Solid oxide electrolysis system with thermal energy storage system

ABSTRACT

An energy storage system converts variable renewable electricity (VRE) to continuous heat at over 1000° C. Intermittent electrical energy heats a solid medium. Heat from the solid medium is delivered continuously on demand. An array of bricks incorporating internal radiation cavities is directly heated by thermal radiation. The cavities facilitate rapid, uniform heating via reradiation. Heat delivery via flowing gas establishes a thermocline which maintains high outlet temperature throughout discharge. Gas flows through structured pathways within the array, delivering heat which may be used for processes including calcination, hydrogen electrolysis, steam generation, and thermal power generation and cogeneration. Groups of thermal storage arrays may be controlled and operated at high temperatures without thermal runaway via deep-discharge sequencing. Forecast-based control enables continuous, year-round heat supply using current and advance information of weather and VRE availability. High-voltage DC power conversion and distribution circuitry improves the efficiency of VRE power transfer into the system.

CROSS-REFERENCE TO RELATED APPLICATIONS

The present application is a continuation of U.S. patent applicationSer. No. 17/537,407, filed Nov. 29, 2021, which in turn claims thebenefit of each of the following applications under 35 USC § 119(e):U.S. Provisional Application No. 63/119,443, filed on Nov. 30, 2020,U.S. Provisional Application No. 63/155,261, filed on Mar. 1, 2021, U.S.Provisional Application No. 63/165,632, filed on Mar. 24, 2021, U.S.Provisional Application No. 63/170,370, filed on Apr. 2, 2021, and U.S.Provisional Application No. 63/231,155, filed on Aug. 9, 2021. Thepresent application also claims the benefit under 35 USC § 119(a)-(d) ofPCT/US21/61041, filed Nov. 29, 2021, which in turn claims the benefit ofthe each of the following as priority applications: U.S. ProvisionalApplication No. 63/119,443, filed on Nov. 30, 2020, U.S. ProvisionalApplication No. 63/155,261, filed on Mar. 1, 2021, U.S. ProvisionalApplication No. 63/165,632, filed on Mar. 24, 2021, U.S. ProvisionalApplication No. 63/170,370, filed on Apr. 2, 2021, and U.S. ProvisionalApplication No. 63/231,155, filed on Aug. 9, 2021. The contents of eachof the aforementioned applications are all incorporated by reference intheir entireties and for all purposes.

BACKGROUND Technical Field

The present disclosure relates to thermal energy storage and utilizationsystems. More particularly, the present disclosure relates to an energystorage system that stores electrical energy in the form of thermalenergy, which can be used for the continuous supply of hot air, carbondioxide (CO₂), steam or other heated fluids, for various applicationsincluding the supply of heat to industrial processes and/or electricalpower generation.

Related Art I. Description of Art

A. Variable Renewable Electricity

The combustion of fossil fuels has been used as a heat source in thermalelectrical power generation to provide heat and steam for uses such asindustrial process heat. The use of fossil fuels has various problemsand disadvantages, however, including global warming and pollution.Accordingly, there is a need to switch from fossil fuels to clean andsustainable energy.

Variable renewable electricity (VRE) sources such as solar power andwind power have grown rapidly as their costs have reduced as the worldmoves towards lower carbon emissions to mitigate climate change. But amajor challenge relating to the use of VRE is, as its name suggests, itsvariability. The variable and intermittent nature of wind and solarpower does not make these types of energy sources natural candidates tosupply the continuous energy demands of electrical grids, industrialprocesses, etc. Accordingly, there is an unmet need for storing VRE tobe able to efficiently and flexibly deliver energy at different times.Moreover, the International Energy Agency has reported that the use ofenergy by industry comprises the largest portion of world energy use,and that three-quarters of industrial energy is used in the form ofheat, rather than electricity. Thus, there is an unmet need forlower-cost energy storage systems and technologies that utilize VRE toprovide industrial process energy, which may expand VRE and reducefossil fuel combustion.

B. Electrochemical Energy Storage Systems

Electrochemical energy storage systems such as lithium-ion batteries andother forms of electrochemistry are commonly used for storingelectricity and delivering it upon demand, or “dispatch.”Electrochemical storage of energy can advantageously respond rapidly tochanges in supply and demand. The high cost of this form of energy,however, has limited its wide adoption. These financial barriers posehurdles to the wider use of electrochemical storage of energy.

C. Storage of Energy as Heat

Thermal energy in industrial, commercial, and residential applicationsmay be collected during one time period, stored in a storage device, andreleased for the intended use during another period. Examples includethe storage of energy as sensible heat in tanks of liquid, includingwater, oils, and molten salts; sensible heat in solid media, includingrock, sand, concrete and refractory materials; latent heat in the changeof phase between gaseous, liquid, and solid phases of metals, waxes,salts and water; and thermochemical heat in reversible chemicalreactions which may absorb and release heat across many repeated cycles;and media that may combine these effects, such as phase-changingmaterials embedded or integrated with materials which store energy assensible heat. Thermal energy may be stored in bulk underground, in theform of temperature or phase changes of subsurface materials, incontained media such as liquids or particulate solids, or inself-supporting solid materials.

Electrical energy storage devices such as batteries typically transferenergy mediated by a flowing electrical current. Some thermal energystorage devices similarly transfer energy into and out of storage usinga single heat transfer approach, such as convective transfer via aflowing liquid or gas heat transfer medium. Notable thermal energystorage devices include heat recuperation devices such as Cowper stovesin steel blast furnaces and “regenerators” in glass melting furnaces,which absorb heat from exiting gases and return heat by preheating inletgases. Such devices use “refractory” materials, which are resistant tohigh temperatures, as their energy storage media. Examples of thesematerials include firebrick and checkerbrick. These materials may bearranged in configurations that allow the passage of air and combustiongases through large amounts of material.

Some thermal energy systems may, at their system boundary, absorb energyin one form, such as incoming solar radiation or incoming electricpower, and deliver output energy in a different form, such as heat beingcarried by a liquid or gas. But thermal energy storage systems must alsobe able to deliver storage economically. For sensible heat storage, therange of temperatures across which the bulk storage material—the“storage medium”—can be heated and cooled is an important determinant ofthe amount of energy that can be stored per unit of material. Thermalstorage materials are limited in their usable temperatures by factorssuch as freezing, boiling, or thermally driven decomposition ordeterioration, including chemical and mechanical effects.

Further, different uses of thermal energy—different heating processes orindustrial processes—require energy at different temperatures.Electrical energy storage devices, for example, can store and returnelectrical energy at any convenient voltage and efficiently convert thatvoltage up or down with active devices. On the other hand, theconversion of lower-temperature heat to higher temperatures isintrinsically costly and inefficient. Accordingly, a challenge inthermal energy storage devices is the cost-effective delivery of thermalenergy with heat content and at a temperature sufficient to meet a givenapplication.

Some thermal energy storage systems store heat in a liquid that flowsfrom a “cold tank” through a heat exchange device to a “hot tank” duringcharging, and then from the hot tank to the cold tank during discharge,delivering relatively isothermal conditions at the system outlet duringdischarge. Systems and methods to maintain sufficient outlet temperaturewhile using lower-cost solid media are needed.

Thermal energy storage systems generally have costs that are primarilyrelated to their total energy storage capacity (how many MWh of energyare contained within the system) and to their energy transfer rates (theMW of instantaneous power flowing into or out of the energy storage unitat any given moment). Within an energy storage unit, energy istransferred from an inlet into storage media, and then transferred atanother time from storage media to an outlet. The rate of heat transferinto and out of storage media is limited by factors including the heatconductivity and capacity of the media, the surface area across whichheat is transferring, and the temperature difference across that surfacearea. High rates of charging are enabled by high temperature differencesbetween the heat source and the storage medium, high surface areas, andstorage media with high heat capacity and/or high thermal conductivity.

But each of these factors can add significant cost to an energy storagedevice. For example, larger heat exchange surfaces commonly require 1)larger volumes of heat transfer fluids, and 2) larger surface areas inheat exchangers, both of which are often costly. Higher temperaturedifferences require heat sources operating at relatively highertemperatures, which may cause efficiency losses (e.g. radiation orconductive cooling to the environment, or lower coefficient ofperformance in heat pumps) and cost increases (such as the selection anduse of materials that are durable at higher temperatures). Media withhigher thermal conductivity and heat capacity may also require selectionof costly higher-performance materials or aggregates.

Another challenge of systems storing energy from VRE sources relates torates of charging. A VRE source, on a given day, may provide only asmall percentage of its full capacity, due to prevailing conditions. Foran energy storage system that is coupled to a VRE source and that isdesigned to deliver continuous output, all the delivered energy must beabsorbed during the period when incoming VRE is available. As a result,the peak charging rate may be some multiple of the discharge rates(e.g., 3-5×), for instance, in the case of a solar energy system, if thedischarge period (overnight) is significantly longer than the chargeperiod (during daylight). In this respect, the challenge of VRE storageis different from, for example, that of heat recuperation devices, whichtypically absorb and release heat at similar rates. For VRE storagesystems, the design of units that can effectively charge at high ratesis important, and may be a higher determinant of total system cost thanthe discharge rate.

1. Cowper Stoves

Examples of solid-media storage designs that achieve relatively higherisothermal conditions during discharge include Cowper stoves, whicharrange a long gas path through successive portions of thermal storagematerial, and which reverse the flow of heat transfer gases betweencharging and discharging.

2. Siemens Electric Thermal Energy Storage (ETES)

This system stores energy as heat in a solid medium such as rocks orrubble that form air passages. The material is heated convectively by aheat transfer fluid that is heated externally to the storage system.European Patent 3 245 388 76 discloses such an approach at FIGS. 1 and 3. However, in this approach, the flow of heat transfer fluid, relativetemperatures, material surface areas, and heat transfer fluid heatersmust all be sufficient to absorb peak incoming energy, and whichincreases costs over components that do not require such high capacity.The necessity for a convective heating system, including a blower system(e.g., a turbo blower system) or the like, adds further cost.Additionally, the solid medium is not able to be heated and cooled in auniform thermocline manner, since both the material and internal fluidpaths are randomly or nonuniformly arranged, and buoyancy effects resultin temperature gradients transverse to the desired gradient. This causesoutlet temperatures to rise relatively early during charging,necessitating more expensive air ducts and fans that can handle hightemperature fluids; and further causes outlet temperatures to fallrelatively early in discharging, limiting the practically achievabledelivery temperature to levels significantly below the peak temperatureof the storage medium (e.g. rock). Because the conversion of electricalenergy is principally via radiation from a resistance heater to adjacentor nearby surfaces, followed by convective heat transfer from thesurfaces to air, followed by convective heat transfer from air to solidmedia; and because each of these heat transfer steps requires adifference in temperature causing heat to flow, the practical peaktemperature of the storage medium is significantly (more than 100° C.)below the peak temperature of the electrical heater surfaces. Becausethe applicability of stored heat varies significantly withtemperature—many industrial processes have a minimum temperaturerequired to drive the process at or above 1000°—and because the cost andusable lifetime of electrical resistance heaters varies sharply withtemperature, any thermal storage system that employs convective charginghas significant disadvantages both in its cost and its field of use.Finally, it is noted that the design disclosed in this reference usesconvective heat transfer, rather than radiation of heat (and reradiationof heat from brick to brick), as the primary method of heating, which isslower and less effective at achieving uniform heating.

Further, during operation of a system according to Siemens/ETES, likeany system employing packed beds of loose/unstructured solids (whetherrocks, gravel, manufactured spheres, or other shapes and methods), thestorage media can be expected to expand and contract repeatedly, andrepeatedly exert high forces during expansion on the outer containerholding the media, and to settle during cooling and shrinking, causingthe media and rubble to settle and potentially be crushed into smallfragments or powder, diminishing their heat capacity. In addition, theexpansion due to heating of bulk, unstructured material as in Siemenscan be expected to exert stress on the container for the bulk material,and thus require the use of expensive insulation and container walls.

3. Conlon

Other approaches have described possible thermal energy storage systemsin the abstract, without enabled designs described or referred to. USPatent Application US2018/0245485A illustrates using solar thermalenergy to heat a liquid storage medium (i.e., molten salt) and refers tothe possibilities of storing heat in solids at [0038] and [0039].However, this approach does not recognize or resolve the problems anddisadvantages, or provide enabling disclosure of the solutions necessaryto enable such storage of VRE in solid media.

4. Stack

Still other approaches have described VRE storage systems with rapidcharging. For example, Stack, in “Performance of firebrickresistance-heated energy storage for industrial heat applications andround-trip electricity storage,” describes design concepts usingelectrical energy as the source energy to heat and store energy inrefractory solids (bricks)(https://doi.org/10.1016/j.apenergy.2019.03.100). Stack discloses aprimary heating method that includes metallic resistive heating elementsembedded within an array of refractory materials that are heated(charged) by radiative heat transfer from such resistive heatingelements to surfaces immediately adjacent to the heating elements, andcooled (discharged) primarily by convective heat discharge using flowingair as the heat transfer fluid, and discloses the optional use ofresistive heating of conductive refractory materials and heating bymeans of passing electrical currents through such conductive refractorymaterials. As discussed below, Stack's primary heating method disclosurehas significant disadvantages versus the present inventions, as theproposed designs have high vulnerability to even small nonuniformitiesin properties of heaters and bricks; high thermal gradients due toreliance on conductive heat transfer and nonuniform heating of surfaces;and high consequences of occurrences of brick failures, including thewell-known cracking and spalling modes. Because the heater wires areexposed to a small amount of brick area and heat transfer is byconduction, nonuniformity in the heating of the refractory material andpotential thermal stress in that material may result, which would beexacerbated in case of failure of individual heater elements, andbecause internal cracking changes conductive heat transfer, any crackedareas result in substantially higher surface temperatures near suchcracks, which may result in significantly higher local temperatures ofheating elements, causing either early-life heater temperatures orsignificant limits in the practical operating temperatures of suchheaters, or both. The present innovations overcome these challenges withboth structural and operational features that allow the reliableoperation of storage media and heaters at high temperatures and longlife by intrinsically assuring more uniformity of temperaturesthroughout the storage media, even in the presence of nonuniformities ofheaters and bricks and cracking and spalling of brick.

5. Others

United States patent application US20180179955A1 is directed to baffledthermoclines in thermodynamic cycle systems. Solid state thermoclinesare used in place of heat exchangers in an energy storage system.However, this teaches limiting the conductive and/or radiative transferof heat within different zones defined by the baffle structure.

United States patent U.S. Pat. No. 9,370,044B2 (McDonald) is directed toa thermal storage device controller that load-balances requirements of auser to manage heating, and discloses the use of bricks with heatingelements disposed in the bricks. Controllers are disclosed that can haveplural operating modes, each operating mode being associated with adefault core temperature, such as a first operating mode and a standbyoperating mode. The operating modes may be set based on a season. TheMcDonald design may also include a controller that receives informationassociated with forecasted climatic conditions, and set operationaltemperatures based on the forecasted climatic conditions. However, thisapproach does not address the above problems and disadvantages withrespect to the charging and discharging of the brick.

II. Problems and Disadvantages

The above-described approaches have various problems and disadvantages.Earlier systems do not take into account several critical phenomena inthe design, construction, and operation of thermal energy storagesystems, and thus does not facilitate such systems being built andefficiently operated. More specifically, current designs fail to address“thermal runaway” and element failure due to non-uniformities in thermalenergy charging and discharging across an array of solid materials,including the design of charging, discharging, and unit controls toattain and restore balances in temperature across large arrays ofthermal storage material.

Thermal energy storage systems with embedded radiative charging andconvective discharging are in principle vulnerable to “thermal runaway”or “heat runaway” effects. The phenomenon may arise from imbalances,even small imbalances, in local heating by heating elements and incooling by heat transfer fluid flow. The variations in heating rate andcooling rate, unless managed and mitigated, may lead to runawaytemperatures that cause failures of heaters and/or deterioration ofrefractory materials. Overheating causes early failures of heatingelements and shortened system life. In Stack, for example, the bricksclosest to the heating wire are heated more than the bricks that arefurther away from the heating wire. As a result, the failure rate forthe wire is likely to be increased, reducing heater lifetime.

One effect that further exacerbates thermal runaway is the thermalexpansion of air flowing in the air conduits. Hotter air expands more,causing a higher outlet velocity for a given inlet flow, and thus ahigher hydraulic pressure drop across the conduit, which may contributeto a further reduction of flow and reduced cooling during discharge.Thus, in successive heating and cooling cycles, progressively less localcooling can occur, resulting in still greater local overheating.

The effective operation of heat supply from thermal energy storagerelies upon continuous discharge, which is a particular challenge insystems that rely upon VRE sources to charge the system. Solutions areneeded that can capture and store that VRE energy in an efficient mannerand provide the stored energy as required to a variety of uses,including a range of industrial applications, reliably and withoutinterruption.

Previous systems do not adequately address problems associated with VREenergy sources, including variations arising from challenging weatherpatterns such as storms, and longer-term supply variations arising fromseasonal variations in VRE generation. In this regard, there is an unmetneed in the art to provide efficient control of energy storage systemcharging and discharging in smart storage management. Current designs donot adequately provide storage management that considers a variety offactors, including medium-term through short-term weather forecasts, VREgeneration forecasts, and time-varying demand for energy, which may bedetermined in whole or in part by considerations such as industrialprocess demand, grid energy demand, real-time electricity prices,wholesale electricity market capacity prices, utility resource adequacyvalue, and carbon intensity of displaced energy supplies. A system isneeded that can provide stored energy to various demands thatprioritizes by taking into these factors, maximizing practical utilityand economic efficiencies.

III. Unmet Needs

There are a variety of unmet needs relating generally to energy, andmore specifically, to thermal energy. Generally, there is a need toswitch from fossil fuels to clean and sustainable energy. There is alsoa need to store VRE to deliver energy at different times in order tohelp meet society's energy needs. There is also a need for lower-costenergy storage systems and technologies that allow VRE to provide energyfor industrial processes, which may expand the use of VRE and thusreduce fossil fuel combustion. There is also a need to maintainsufficient outlet temperature while using lower-cost solid media.

Still further, there is a need to design VRE units that can be rapidlycharged at low cost, supply dispatchable, continuous energy as requiredby various industrial applications despite variations in VRE supply, andthat facilitate efficient control of charging and discharging of theenergy storage system.

SUMMARY

The example implementations advance the art of thermal energy storageand enable the practical construction and operation of high-temperaturethermal energy storage systems which are charged by VRE, store energy insolid media, and deliver high-temperature heat.

Aspects of the example implementations relate to a system for thermalenergy storage, including an input, (e.g., electricity from a variablerenewable electricity (VRE) source), a container having sides, a roofand a lower platform, a plurality of vertically oriented thermal storageunits (TSUs), inside the container, the TSUs each including a pluralityof stacks of bricks and heaters attached thereto, each of the heatersbeing connected to the input electricity via switching circuitry, aninsulative layer interposed between the plurality of TSUs, the roof andat least one of the sides, a duct formed between the insulative layerand a boundary formed by the sides, an inner side of the roof and thelower platform of the container, a blower that blows relatively coolerfluid such as air or another gas (e.g. CO₂) along the flow path, anoutput (e.g., hot air at prescribed temperature to industrialapplication), a controller that controls and co-manages the energyreceived from the input and the hot air generated at the output based ona forecast associated with an ambient condition (e.g., season orweather) or a condition (e.g., output temperature, energy curve, etc.).The exterior and interior shapes of the container may be rectangular,cylindrical (in which case “sides” refers to the cylinder walls), orother shapes suitable to individual applications.

The terms air, fluid and gas are used interchangeably herein to refer toa fluid heat transfer medium of any suitable type, including varioustypes of gases (air, CO₂, oxygen and other gases, alone or incombination), and when one is mentioned it should be understood that theothers can equally well be used. Thus, for example, “air” can be anysuitable fluid or gas or combinations of fluids or gases.

According to another aspect, with regard to the TSUs as explained above,the bricks are configured in arrays. The bricks have elongate channelsor slots through them, which are vertically oriented in the stack andinduce turbulent flow for effective heat transfer to the fluid flowingthrough the stack. The arrays of bricks define radiation chambers,either between bricks or formed within the bricks themselves, or both,which enable efficient distribution and absorption of heat energythrough the stack by exposing surfaces of bricks directly or indirectlyto heat radiation from the heater elements, heating brick throughout thestack more quickly and uniformly than by conduction or convection alone,particularly at high temperatures. The elongate channels have a longaxis and a short axis, and may have curved or rounded corners.

The bricks may be stacked in a 3D alternating (e.g., checkerboard)pattern, with alternating brick-chamber-brick, etc. In each dimension(x, y, z). Vertical air flow paths are formed through channels in atleast some of the bricks, then through the next radiation chamber, thenthrough the next channels of a subsequent brick, and so on, from thebottom of the stack to the top. Resistive heaters are positioned in gapsformed between bricks, orthogonal to the channels, to heat the stackusing incoming electricity (from an energy source, such as solar, wind,etc.). A blower directs air from the bottom of the stack to the top todischarge the stack and provide hot air for industrial use. In someimplementations, the stacks are enclosed in a structure that is designedfor seismic isolation to avoid damage during a seismic event such as anearthquake. The structure is also designed for the circulation of airfrom the blower through pathways surrounding the core array structure,to provide dynamic insulation between the stacks, the foundation and thestructure. One arrangement provides such circulation to an upper portionof the structure, and then down one or more sides of the structure, andthen up through the brick array to heat the air to a desired temperaturerange for discharge to industrial uses.

Thermal energy storage (TES) systems according to the present designscan advantageously be integrated with or coupled to steam generators,including heat recovery steam generators (HRSGs) and once-through steamgenerators (OTSGs). The terms “steam generator”, “HRSG”, and “OTSG” areused interchangeably herein to refer to a heat exchanger that transfersheat from a first fluid into a second fluid, where the first fluid maybe air circulating from the TSU and the second fluid may be water (beingheated and/or boiled), oil, salt, air, CO2, or another fluid. In suchimplementations, the heated first fluid is discharged from a TES unitand provided as input to the steam generator, which extracts heat fromthe discharged fluid to heat a second fluid, including producing steam,which heated second fluid may be used for any of a variety of purposes(e.g. to drive a turbine to produce shaft work or electricity). Afterpassing through a turbine, the second fluid still contains significantheat energy, which can be used for other processes. Thus, the TES systemmay drive a cogeneration process. The first fluid, upon exiting thesteam generator, can be fed back as input to the TES, thus capturingwaste heat to effectively preheat the input fluid. Waste heat fromanother process may also preheat input fluid to the TES.

According to yet another aspect, an integrated thermal energy storagecalciner system is provided. The TES unit delivers a gaseous fluidoutput connected to a calciner or kiln, wherein the gaseous fluid outputprovides a first portion of the heat and/or temperature required todrive the calcination process, and an optional second heat source mayprovide further energy and/or temperature. The TES unit may have agaseous fluid output directly connected to all or any portion of amaterial transformation system that includes material drying, preheatingor other conditioning, and calcination, wherein the TES provides all orsubstantially all of the energy required to drive such materialtransformation processes. The TES unit in some applications has agaseous fluid output indirectly connected to a calciner/kiln foractivation of a material to remove unwanted substances (for example CO₂,in a calcination process for cement production), wherein the gaseousfluid output is configured to provide a primary working fluid at ahigher temperature that exchanges heat with a secondary working fluid ata lower temperature that in turn heats a solid raw material. The primaryworking gas is hot gas for convective heat transfer (e.g., at thecalcination plant). A feedback system may recirculate the post-processgas to the TES for reheating. Applications may include constructionmaterial, biomass and/or food processing.

Additional aspects may include a solid-oxide electrolysis applicationthat includes the TES unit coupled to an electrolysis system. Ahigh-temperature solid oxide electrolyzer converts water into hydrogenand oxygen in a hydrogen generation unit (e.g., for use in a fuel cell).The electrolyzer includes an anode, a cathode and a solid ceramic(oxide) electrolyte, and uses heat (e.g., output of the thermal energystorage (TES)) to decrease the electrical energy needed to be used inthe electrolysis process. The heat that flows from the TES stack isreceived at the solid oxide electrolysis cells (SOEC) as hot air and/orsteam, at a rate that is determined by a controller (manual and/orautomatic) that sets the flow rate to maintain the SOEC at a desiredtemperature (e.g., 860° C.). The electricity source may be any of avariety of sources, such as a photovoltaic (PV) cell, an electricityoutput application associated with the TES, or stored electricity at theSOEC itself. The hydrogen generated by the SOEC by may be used in a widevariety of known applications, including in a hydrogen filling station(e.g., electric vehicle charging station), or other industrialapplication (e.g., renewable diesel refinery), and the highly oxygenatedby-product may also be used for industrial or commercial applications,including power generation. The lower-temperature waste heat released bythe SOEC (e.g. at 650° C.) can optionally be directed and optionallysupplemented by higher-temperature heat by the TES, and coupled into asteam generator for the use of such heat or used for another industrialprocess. As an alternative to electrolysis of water to hydrogen,electrolysis of other gases may be performed, such as carbon dioxide tocarbon monoxide, either separately or in combination with electrolysisof water.

According to an additional aspect, a DC/DC power conversion systemincludes an array of galvanically isolated individual converters, eachreceiving an input from a photovoltaic (PV) array at a primary side, asecondary side of each of the individual converters coupled in seriesfor higher output voltage, and in parallel for higher output current, acombiner coupled to the array and other arrays, and a junction boxincluding a plurality of high voltage switches coupled, by a variable DCline to the combiner, having an output to a thermal storage unit (TSU)or a DC charging system.

According to another aspect, a dynamic insulation system include acontainer having sides, a roof and a lower platform, a plurality ofvertically oriented thermal storage units (TSUs) spaced apart from oneanother, an insulative layer interposed between the plurality of TSUs,the roof and at least one of the sides and floor, a duct formed betweenthe insulative layer and a boundary formed by the sides, an inner sideof the roof and the lower platform of the container, and a blower thatblows unheated air along the air flow path, upward from the platform toa highest portion of the upper portion, such that the air path is formedfrom the highest portion of the roof to the platform, and is heated bythe plurality of TSUs, and output from the TES apparatus. The unheatedair along the flow path forms an insulated layer and is preheated byabsorbing heat from the insulator.

Further aspects include applications associated with a carbon dioxideseparator. The separation of carbon dioxide from other gases includingambient air and combustion exhaust gases is often beneficiallyaccomplished by processes that use large amounts of heat to regenerate achemical that absorbs or reacts with carbon dioxide. Such processesinclude but are not limited to processes that use acarbonation/calcination reaction cycle, for example using calcium orpotassium reactions, or absorption/adsorption/release cycles, forexample using liquid or solid materials including zeolites or amines.The provision of heat to serve these capture processes from VRE may bebeneficial in further reducing the emissions and costs such of carboncapture processes. For example, a combustion exhaust gas input from anindustrial source, or from a direct air capture (DAC) unit, may requireheat to drive a solvent “reboiler,”-a steam generator or a calciumcarbonate calciner, to raise the temperature of a reactant that causesthe release separation of carbon dioxide. The combustion exhaust gas isreceived via a heat exchanger and a stripper tower. A carbon dioxidecompressor receives power generated by a steam turbine connected to theTES system, and compresses the selectively separated carbon dioxide.Compressed carbon dioxide may be input to a solid oxide electrolysiscell (SOEC), industrial processes, or geologic sequestration.

BRIEF DESCRIPTION OF DRAWINGS

The accompanying drawings are included to provide a furtherunderstanding of the present disclosure and are incorporated in andconstitute a part of this specification. The drawings illustrate exampleimplementations of the present disclosure and, together with thedescription, serve to explain the principles of the present disclosure.

In the drawings, similar components and/or features may have the samereference label. Further, various components of the same type may bedistinguished by following the reference label with a second label thatdistinguishes among the similar components. If only the first referencelabel is used in the specification, the description is applicable to anyone of the similar components having the same first reference labelirrespective of the second reference label.

FIG. 1 illustrates a schematic diagram of the thermal energy storagesystem architecture according to the example implementations;

FIG. 2 illustrates a schematic diagram of a system according to theexample implementations;

FIG. 3 illustrates a schematic diagram of a system according to theexample implementations;

FIG. 4 illustrates a schematic diagram of a storage-fired once-throughsteam generator (OTSG) according to the example implementations;

FIG. 5 illustrates a schematic diagram of the pipe of the OTSG accordingto the example implementations;

FIG. 6 illustrates an example view of a system being used as anintegrated cogeneration system according to the example implementations;

FIG. 7 illustrates an outer view of the thermal energy storage systemaccording to the example implementations;

FIG. 8 illustrates an isometric view of the inner roof and storagestructure of the thermal energy storage system according to the exampleimplementations;

FIG. 9 illustrates a top view of the inner roof of a thermal storagestructure according to an example implementation.

FIG. 10 illustrates a view of a platform at a lower portion of thethermal energy storage system according to the example implementations;

FIG. 11 illustrates a view of the seismic reinforcing structure of thethermal energy storage system according to the example implementations;

FIG. 12 illustrates a view of the support structure for the bricks ofthe thermal energy storage system according to the exampleimplementations;

FIG. 13 illustrates the blowers and louvers of the thermal energystorage system according to the example implementations;

FIG. 14 illustrates dynamic insulation according to the exampleimplementations;

FIG. 15 is a block diagram illustrating an implementation of variouscontrol systems;

FIG. 16 is a block diagram illustrating an implementation of a thermalstorage control system;

FIG. 17 is a block diagram illustrating an implementation of an externalanalytics system;

FIG. 18 illustrates an air bypass heater according to the exampleimplementations;

FIGS. 19A-19D, 20A-20C and 21 illustrate charge and discharge of thethermal energy storage system according to the example implementations;

FIG. 22 illustrates the system during charge and discharge statesaccording to the example implementations;

FIG. 23 illustrates a schematic view of thermal runaway according to theexample implementations;

FIGS. 24A and 24-29 illustrate schematic views of lead-lag according tothe example implementations;

FIG. 30 is a block diagram illustrating definition of a deep-dischargetemperature based its relative closeness to two reference temperatures.

FIG. 31 is a block diagram illustrating definition of a deep-dischargetemperature based on a difference from the bypass temperature.

FIG. 32 is a table illustrating an example in which each of N storagearrays (N=3) is deep-discharged once during every N discharge periods.

FIG. 33 is a table illustrating an example in which each of N storagearrays is deep-discharged multiple times and partially discharged onceduring every N discharge periods.

FIGS. 34(A)-(C) illustrate power profiles according to the exampleimplementations;

FIGS. 35(A)-(B) illustrate a flowchart associated with startup andshutdown according to the example implementations;

FIGS. 36 and 37 illustrate the structure of the radiation cavity andpropagation of thermal radiation and temperature characteristics, andcorresponding fluid slot, according to some implementations.

FIG. 38 illustrates a view of a brick according to the exampleimplementations;

FIG. 39 illustrates a view of a brick according to the exampleimplementations;

FIG. 40 illustrates a view of a brick according to the exampleimplementations;

FIG. 41 illustrates interlocking bricks according to the exampleimplementations;

FIG. 42 illustrates an example refractory stack according to the exampleimplementations;

FIG. 43 illustrates an example perspective view of stacking of thebricks according to the example implementations;

FIG. 44 illustrates an example side view of stacking of the bricksaccording to the example implementations;

FIG. 45 illustrates an example upper perspective view of stacks ofbricks arranged in rows according to the example implementations;

FIG. 46 is a diagram showing an isometric view of an assemblage ofthermal storage blocks;

FIG. 47 is a diagram showing an exploded perspective view of the blocksof FIG. 46 ;

FIG. 48 is a diagram showing a top-down view of the blocks of FIG. 46 ,according to some implementations;

FIG. 49 is a diagram showing a top-down view of one or more thermalstorage blocks, according to some implementations;

FIG. 50 is an isometric view of the block(s) of FIG. 49 according to theexample implementations;

FIG. 51 is a side view of the block(s) of FIG. 49 according to theexample implementations;

FIG. 52 illustrates an example stack of bricks with plural columnsaccording to the example implementations;

FIG. 53 illustrates a side view of the stacks of bricks and HRSG in thethermal energy storage system to the example implementations;

FIG. 54 illustrates an isometric view of the structure including thestacks of bricks and HRSG in the thermal energy storage system accordingto the example implementations;

FIG. 55 illustrates an isometric view of the frame and the output regionof stacks of bricks in the thermal energy storage system according tothe example implementations;

FIG. 56 illustrates an isometric view from below of the thermal energystorage system according to the example implementations;

FIG. 57 illustrates an isometric view of the thermal energy storagesystem according to the example implementations;

FIG. 58 provides an isometric view of another example thermal storageunit including failsafe vent panel, according to some implementations.

FIG. 59 provides an isometric view of the thermal storage unit withmultiple vents closures open, according to some implementations.

FIG. 60 provides an isometric view of the thermal storage unit withmultiple vents closures closed and cutaways in the outer enclosure,according to some implementations.

FIG. 61 provides a more detailed perspective view of the primary ventclosure, according to some implementations.

FIG. 62 provides a still more detailed perspective view of a hinge forthe primary vent closure, according to some implementations.

FIG. 63 illustrates a composition of a brick according to the exampleimplementations;

FIG. 64 shows a stationary auger and diverters according to the exampleimplementations;

FIG. 65 shows the diverters with the above aspects of flow mixingaccording to the example implementations;

FIG. 66(A)-(C) illustrate various configurations of the resistiveheating elements according to the example implementations;

FIGS. 67, 68 and 69 illustrate various configurations of the resistiveheating element according to the example implementations;

FIG. 70 illustrates configurations of the resistive heating elementaccording to the example implementations;

FIG. 71 is a block diagram of an implementation of a power transmissionsystem for a renewable energy source;

FIG. 72 is a block diagram of an implementation of power transmissionsystem for a renewable energy source;

FIG. 73 is a block diagram of an implementation of power receiver systemfor a transmitted direct current voltage;

FIG. 74 is a block diagram of an implementation of a converter circuit;

FIG. 75 is a flow diagram depicting an implementation of a method foroperating a DC power transfer system;

FIG. 76 illustrates a material activation system according to an exampleimplementation;

FIG. 77 illustrates a calciner with the thermal energy storage systemaccording to an example implementation;

FIG. 78 illustrates a calciner with the thermal energy storage systemaccording to an example implementation;

FIG. 79 illustrates an integrated fuel-fired and renewable heat andpower system powering a calciner with the thermal energy storage systemaccording to an example implementation;

FIG. 80 illustrates a solid-oxide electrolyzer co-electrolyzing CO₂ andwater, connected to a Sabatier and/or Fischer-Tropsch apparatusintegrated with a calciner and with a thermal energy storage systemaccording to an example implementation;

FIG. 81 illustrates schematic diagrams of a material activation process;

FIG. 82 illustrates schematic diagrams of various implementations of amaterial activation process with a thermal energy storage systemaccording to an example implementation;

FIG. 83 illustrates schematic diagrams of various implementations of acalciner for the Bayer process, including the calcination step, with thethermal energy storage system according to an example implementation;

FIG. 84 provides an illustration of a solid oxide unit as a fuel celland as an electrolyzer according to the example implementations;

FIG. 85 illustrates the electrolysis mode according to the exampleimplementations;

FIG. 86 illustrates the fuel cell mode according to the exampleimplementations;

FIG. 87 illustrates an example system used to power the production ofhydrogen and/or hydrocarbon fuels by delivering both heat and power todrive a high-temperature solid-oxide electrolyzer, according to theexample implementations;

FIG. 88 illustrates a reversible solid oxide electrolysis system 4800according to the example implementations.

FIG. 89 illustrates a system 550 integrated with a combined cycle powerplant to provide a thermal storage for operation of a steam power plantincluding optional cogeneration according to the exampleimplementations;

FIG. 90 illustrates integrated cogeneration system capable of deliveringhigh-pressure steam as well as electric power according to the exampleimplementations;

FIG. 91 illustrates an industrial process plant integrated with athermal energy storage system according to the example implementations;

FIG. 92 illustrates a process for apportioning variable renewableelectricity to multiple uses on a typical day;

FIG. 93 illustrates an electric booster according to the exampleimplementations;

FIG. 94 illustrates integrated cogeneration system associated withcarbon capture, according to the example implementations;

FIG. 95 is a flow diagram depicting an implementation of a method foroperating a thermal energy storage system;

FIG. 96 is a flow diagram depicting an implementation of a method foroperating a carbon dioxide capture system;

FIG. 97 discloses a system having a fuel-fired heater 9905 and a thermalstorage unit according to the example implementations;

FIG. 98 illustrates process according to the example implementations;

FIG. 99 illustrates a first forecast energy availability second forecastenergy availability of multi-day availability according to the exampleimplementations; and

FIG. 100 illustrates a direct air capture approach according to theexample implementations.

DETAILED DESCRIPTION

Aspects of the example implementations, as disclosed herein, relate tosystems, methods, materials, compositions, articles, and improvementsfor a thermal energy storage system for power generation for variousindustrial applications.

I. Overall System

Problems to be Solved

The present disclosure is directed to effectively storing VRE as thermalenergy in solid storage media.

While systems such as Cowper stoves store high-temperature energy insolid media, such units are charged and discharged at similar rates, andare heated and cooled primarily by convection, by flowing heat transfergases. Pressure differences caused by any combination ofbuoyancy-mediated draft (the “stack effect”) and induced or forced flow(i.e., flow caused by a fluid movement system which may include fans orblowers) moves the heat transfer fluids through the solid media.Approaches such as this use convection for charge and discharge, withthe heat transfer fluid being heated externally to the storage mediaarray. But applying this approach to VRE storage disadvantageouslyrequires large surface area and is therefore costly, because suchconvective heat transfer systems must operate at the much higher ratesassociated with VRE charging than heat delivery.

Thermal storage systems include various element heaters, storage media,enclosing structures, and heat transfer subsystems, all of which may beaffected by temperatures of the storage system and by the rate of changeof such temperatures. Excessive temperatures and/or excessive rate ofchange of temperature can induce failures due to various effects. Someof these effects include material softening, oxide spallation, metalrecrystallization, oxidation, and thermal stress-induced cracking andfailure.

Rising temperatures within a thermal storage unit cause thermalexpansion of the materials that are used for thermal energy storage.Nonuniformities in these temperatures can cause stress in solids. Suchtemperature nonuniformities may arise during both discharging periods(due to flowing heat transfer fluids that cool the storage media) andcharging periods (due to the high heat transfer rate). In general, aheat flux at one surface causes nonuniform temperatures within the solidmedia; such temperature nonuniformity causes heat to flow by conductionto cooler zones, at a rate determined by the thermal conductivity of thematerial and the magnitude of the temperature nonuniformity.

Temperature nonuniformities may also be caused by repeated heating andcooling of a thermal storage array that includes heating elements andchannels through which the heat transfer fluid flows. Thesenonuniformities may be amplified in successive cycles of heating andcooling, which in turn causes localized areas of a storage system tobecome excessively hot or cool during operation. This phenomenon isknown as “thermal runaway,” and can lead to early-life failure ofthermal storage arrays. Nonuniformities in temperature may beexacerbated when individual heating elements fail, resulting in the zoneof a storage unit having the failed heating elements being unheated,while another zone of the storage unit continues to have active heatingelements and high temperatures.

Finally, VRE storage systems must operate under an exacting set ofstandards. They should be able to fully charge during periods that thevariable energy is available (e.g., during daylight hours in the case ofsolar energy, as defined by a solar diurnal cycle that begins with thetime of sunrise and ends with the time of sunset; it is understood thatthe time of sunrise and sunset can vary depending on physical locationin terms of latitude and longitude, geography in terms of terrain, date,and season). They need to consistently deliver energy, even though theirinput energy source is not always predictably available. This means thatthese systems must sometimes be able to deliver output energy duringperiods that are longer than the periods of input-energy availability.VRE storage systems need to be able to operate under these conditionsdaily over decades of use.

Overview of Solution

The present disclosure relates to the field of thermal energy storageand utilization systems, and addresses the above-noted problems. Athermal energy storage system is disclosed that stores electrical energyin the form of thermal energy in a charging mode, and delivers thestored energy in a discharging mode. The discharging can occur at thesame time as charging; i.e., the system may be heated by electricalenergy at the same time that it is providing a flow of convectivelyheated air. The discharged energy is in the form of hot air, hot fluidsin general, steam, heated CO₂, heated supercritical CO₂, and/orelectrical power generation, and can be supplied to variousapplications, including industrial uses. The disclosed implementationsinclude efficiently constructed, long-service-life thermal energystorage systems having materials, fabrication, physical shape, and otherproperties that mitigate damage and deterioration from repeatedtemperature cycling.

Optionally, heating of the elements of the storage unit may beoptimized, so as to store a maximum amount of heat during the chargingcycle. Alternatively, heating of elements may be optimized to maximizeheating element life, by means including minimizing time at particularheater temperatures, and/or by adjusting peak charging rates and/or peakheating element temperatures. Still other alternatives may balance thesecompeting interests. Specific operations to achieve these optimizationsare discussed further below.

Example implementations employ efficient yet economical thermalinsulation. Specifically, a dynamic insulation design may be used eitherby itself or in combination with static primary thermal insulation. Thedisclosed dynamic insulation techniques provide a controlled flow of airinside the system to restrict dissipation of thermal energy to theoutside environment, which results in higher energy storage efficiency.

System Overview

FIG. 1 is a block diagram of a system 1 that includes a thermal energystorage system 10, according to one implementation. In theimplementation shown, thermal energy storage system 10 is coupledbetween an input energy source 2 and a downstream energy-consumingprocess 22. For ease of reference, components on the input and outputsides of system 1 may be described as being “upstream” and “downstream”relative to system 10.

In the depicted implementation, thermal energy storage system 10 iscoupled to input energy source 2, which may include one or more sourcesof electrical energy. Source 2 may be renewable, such as photovoltaic(PV) cell or solar, wind, geothermal, etc. Source 2 may also be anothersource, such as nuclear, natural gas, coal, biomass, or other. Source 2may also include a combination of renewable and other sources. In thisimplementation, source 2 is provided to thermal energy storage system 10via infrastructure 4, which may include one or more electricalconductors, commutation equipment, etc. In some implementations,infrastructure 4 may include circuitry configured to transportelectricity over long distances; alternatively, in implementations inwhich input energy source 2 is located in the immediate vicinity ofthermal energy storage system 10, infrastructure 4 may be greatlysimplified. Ultimately, infrastructure 4 delivers energy to input 5 ofthermal energy storage system 10 in the form of electricity.

The electrical energy delivered by infrastructure 4 is input to thermalstorage structure 12 within system 10 through switchgear, protectiveapparatus and active switches controlled by control system 15. Thermalstorage structure 12 includes thermal storage 14, which in turn includesone more assemblages (e.g., 14A, 14B) of solid storage media (e.g., 13A,13B) configured to store thermal energy.

These assemblages are variously referred to throughout this disclosureas “stacks,” “arrays,” and the like. These terms are intended to begeneric and not connote any particular orientation in space, etc. Ingeneral, an array can include any material that is suitable for storingthermal energy and can be oriented in any given orientation (e.g.,vertically, horizontally, etc.). Likewise, the solid storage mediawithin the assemblages may variously be referred to as thermal storageblocks, bricks, etc. In implementations with multiple arrays, the arraysmay be thermally isolated from one another and are separatelycontrollable, meaning that they are capable of being charged ordischarged independently from one another. This arrangement providesmaximum flexibility, permitting multiple arrays to be charged at thesame time, multiple arrays to be charged at different times or atdifferent rates, one array to be discharged while the other arrayremains charged, etc.

Thermal storage 14 is configured to receive electrical energy as aninput. As will be explained in greater detail below, the receivedelectrical energy may be provided to thermal storage 14 via resistiveheating elements that are heated by electrical energy and emit heat,primarily as electromagnetic radiation in the infrared and visiblespectrum. During a charging mode of thermal storage 14, the electricalenergy is released as heat from the resistive heating elements,transferred principally by radiation emitted both by the heatingelements and by hotter solid storage media, and absorbed and stored insolid media within storage 14. When an array within thermal storage 14is in a discharging mode, the heat is discharged from thermal storagestructure 12 as output 20. As will be described, output 20 may takevarious forms, including a fluid such as hot air. (References to the useof “air” and “gases” within the present disclosure may be understood torefer more generally to a “fluid.”) The hot air may be provided directlyto a downstream energy consuming process 22 (e.g., an industrialapplication), or it may be passed through a steam generator (not shown)to generate steam for process 22. More detail regarding steam generationis provided later in this Section, and more detail regarding variouspotential downstream processes is provided in Section IV.

Additionally, thermal energy storage system 10 includes a control system15. Control system 15, in various implementations, is configured tocontrol thermal storage 14, including through setting operationalparameters (e.g., discharge rate), controlling fluid flows, controllingthe actuation of electromechanical or semiconductor electrical switchingdevices, etc. The interface 16 between control system 15 and thermalstorage structure 12 (and, in particular thermal storage 14) isindicated in FIG. 1 . Control system 15 may be implemented as acombination of hardware and software in various embodiments. More detailregarding possible implementations of control system 15 is providedbelow with respect to FIGS. 15 through 17 .

Control system 15 may also interface with various entities outsidethermal energy storage system 10. For example, control system 15 maycommunicate with input energy source 2 via an input communicationinterface 17B. For example, interface 17B may allow control system 15 toreceive information relating to energy generation conditions at inputenergy source 2. In the implementation in which input energy source 2 isa photovoltaic array, this information may include, for example, currentweather conditions at the site of source 2, as well as other informationavailable to any upstream control systems, sensors, etc. Interface 17Bmay also be used to send information to components or equipmentassociated with source 2.

Similarly, control system 15 may communicate with infrastructure 4 viaan infrastructure communication interface 17A. In a manner similar tothat explained above, interface 17A may be used to provideinfrastructure information to control system 15, such as current orforecast VRE availability, grid demand, infrastructure conditions,maintenance, emergency information, etc. Conversely, communicationinterface 17A may also be used by control system 15 to send informationto components or equipment within infrastructure 4. For example, theinformation may include control signals transmitted from the controlsystem 15, that controls valves or other structures in the thermalstorage structure 12 to move between an open position and a closedposition, or to control electrical or electronic switches connected toheaters in the thermal storage 14. Control system 15 uses informationfrom communication interface 17A in determining control actions, andcontrol actions may adjust closing or firing of switches in a manner tooptimize the use of currently available electric power and maintain thevoltage and current flows within infrastructure 4 within chosen limits.

Control system 15 may also communicate downstream using interfaces 18Aand/or 18B. Interface 18A may be used to communicate information to anyoutput transmission structure (e.g., a steam transmission line), whileinterface 18B may be used to communicate with downstream process 22. Forexample, information provided over interfaces 18A and 18B may includetemperature, industrial application demand, current or future expectedconditions of the output or industrial applications, etc. As will beexplained in greater detail below, control system 15 may control theinput, heat storage, and output of thermal storage structure based on avariety of information. As with interfaces 17A and 17B, communicationover interfaces 18A and 18B may be bidirectional—for example, system 10may indicate available capacity to downstream process 22.

Still further, control system 15 may also communicate with any otherrelevant data sources (indicated by reference numeral 21 in FIG. 1 ) viaadditional communication interface 19. Additional data sources 21 arebroadly intended to encompass any other data source not maintained byeither the upstream or downstream sites. For example, sources 21 mightinclude third-party forecast information, data stored in a cloud datasystem, etc.

As will be described in detail below, thermal energy storage system 10is configured to efficiently store thermal energy generated from inputenergy source 2, and deliver output energy in various forms to adownstream process 22. In various implementations, input energy source 2may be from renewable energy and downstream process 22 may be anindustrial application that requires an input such as steam or hot air.Through various techniques, including arrays of thermal storage blocksthat use radiant heat transfer to efficiently storage energy and alead-lag discharge paradigm that leads to desirable thermal propertiessuch as the reduction of temperature nonuniformities within thermalstorage 14, system 10 may advantageously provide a continuous (ornear-continuous) flow of output energy based on an intermittentlyavailable source. The use of such a system has the potential to reducethe reliance of industrial applications on fossil fuels.

FIG. 2 provides a schematic view of one implementation of a system 200for storing thermal energy, and further illustrates components andconcepts just described with respect to FIG. 1 . As shown, one or moreenergy sources 201 provide input electricity. For example, and as notedabove, renewable sources such as wind energy from wind turbines 201 a,solar energy from photovoltaic cells 201 b, or other energy sources mayprovide electricity that is variable in availability or price becausethe conditions for generating the electricity are varied. For example,in the case of wind turbine 201 a, the strength, duration and varianceof the wind, as well as other weather conditions causes the amount ofenergy that is produced to vary over time. Similarly, the amount ofenergy generated by photovoltaic cells 201 b also varies over time,depending on factors such as time of day, length of day due to the timeof year, level of cloud cover due to weather conditions, temperature,other ambient conditions, etc. Further, the input electricity may bereceived from the existing power grid 201 c, which may in turn varybased on factors such as pricing, customer demand, maintenance, andemergency requirements.

The electricity generated by source 201 is provided to the thermalstorage structure within the thermal energy storage system. In FIG. 2 ,the passage of electricity into the thermal storage structure isrepresented by wall 203. (More details as to the thermal storagestructure are provided below with respect to FIGS. 7 through 12 .) Theinput electrical energy is converted to heat within thermal storage 205via resistive heating elements 207 controlled by switches (not shown).Heating elements 207 provide heat to solid storage media 209. As will beexplained in greater detail in Section II, thermal storage components(sometimes called “bricks”) within thermal storage 205 are arranged toform embedded radiative chambers. FIG. 2 illustrates that multiplethermal storage arrays 209 may be present within system 200. Thesearrays may be thermally isolated from one another and may be separatelycontrollable. FIG. 2 is merely intended to provide a conceptualrepresentation of how thermal storage 205 might be implemented—one suchimplementation might, for example, include only two arrays, or mightinclude six arrays, or ten arrays, or more.

In the depicted implementation, a blower 213 drives air or other fluidto thermal storage 205 such that the air is eventually received at alower portion of each of the arrays 209. The air flows upward throughthe channels and chambers formed by bricks in each of the arrays 209,with flow controlled by louvers (as shown 1611 in FIG. 18 ). By therelease of heat energy from the resistive heating elements 207, heat isradiatively transferred to arrays 209 of bricks during a charging mode.Relatively hotter brick surfaces reradiate absorbed energy (which may bereferred to as a radiative “echo”), and participate in heating coolersurfaces. During a discharging mode, the heat stored in arrays 209 isoutput, as indicated at 215.

Once the heat has been output in the form of a fluid such as hot air,the fluid may be provided for one or more downstream applications. Forexample, hot air may be used directly in an industrial process that isconfigured to receive the hot air, as shown at 217. Further, hot air maybe provided as a stream 219 to a heat exchanger 218 of a steam generator222, and thereby heats a pressurized fluid such as air, water, CO₂ orother gas. In the example shown, as the hot air stream 219 passes over aline 221 that provides the water from the pump 223 as an input, thewater is heated and steam is generated as an output 225, which may beprovided to an industrial application as shown at 227.

FIG. 3 provides a schematic view of a distributed control system 300that highlights certain control aspects that may be present inparticular implementations of the teachings of the present disclosure.As has been previously described, energy inputs to system 300 mayinclude VRE sources (such as photovoltaic cells 310 and/or wind turbines320), as well as other sources 340. Control system 300, which may bereferred to as a “smart energy controller,” is configured to exchangeinformation with a variety of components within system 300, includingthermal energy storage control system 399 (also referred to as controlsystem 399 for convenience) to automatically manage the operation ofcharging, discharging, and maintaining thermal energy storage in anintelligent manner.

Control system 399 may include a variety of sensors/devices, includingone or more voltage and current sensors integrated with powerconditioning equipment 311 and switching equipment 303, a wind sensor301, a sky camera 302 that detects passing clouds, and/or solarradiation sensor 303. Control system 399 may also receive data via anetwork connection from various remote data sources, such as cloud datasource 304. Accordingly, control system 399 may access many differentforms of information, including, for example, weather forecasts andmarket conditions such as the availability of electricity, cost ofelectricity, presence of other energy sources, etc.

Control system 399 is also configured to communicate with input energysources via power conversion and control devices such as 303, 311, 321,and 341. These controllers may be configured not only to pass data tocontrol system 399, but also to receive commands from control system399. Control system 399 may be configured in some instances to switchbetween input power sources in some instances by communicating withthese controllers. Accordingly, in one implementation, control system399 might analyze numerous different external data sources to determinewhich of several available input energy sources should be utilized, andthen communicate with controllers such as 311 and 321 to select an inputsource. In a similar fashion, control system 399 may also communicatewith downstream devices or systems, such as a steam generator 334, a hotair output 335, and an industrial application 336. Control system 399may use information from such input sensors to determine actions such asselectively activating switches 303-1 through 303-N, controlling heaterswithin array 330. Such control actions may include rapid-sequenceactivation of switches 303-1 through 303-N in patterns to presentvarying total resistive loads in response to varying available power, soas to manage voltage and current levels at controllers 311, 321, and 341within predetermined ranges.

Information within the thermal storage structure itself may also be usedby control system 399. For example, a variety of sensors andcommunication devices may be positioned within the bricks, arrays,storage units and other locations within the thermal storage structure,as represented as electrical switches, including semiconductor switches,by 303-1 through 303-N. The information may include state of charge,temperature, valve position, and numerous other operating parameters,and the switches may control the operation of the thermal storage system330, based on a signal received from the control system 399, forexample. Such control actions may include activation of switches 303-1through 303-N so as to manage temperatures and state of charge withinarray within predetermined ranges.

Control system 399 can communicate with devices such as 303 to performoperations based on received data that may be either internal and/orexternal to the thermal storage structure. For example, control system399 may provide commands to heating elements controls, power supplyunits, discharge blowers pumps, and other components to performoperations such as charging and discharging. Control system 399 mayspecifically receive data from thermal storage system 330, includingfrom subsections such as 350, and individual bricks or heating elementssuch as 305-1 through 305-N.

The ability to receive data from numerous locations inside and outsidethe thermal storage structure permits system 300 to be able to operatein a flexible and efficient manner, which is advantageous given thechallenges that arise from attempting to deliver a continuous supply ofoutput energy from a variable source.

A thermal storage structure such as that depicted in FIGS. 1-3 may alsoinclude output equipment configured to produce steam for use in adownstream application. FIG. 4 , for example, depicts a block diagram ofan implementation of a thermal storage structure 400 that includes astorage-fired once-through steam generator (OTSG). An OTSG is a type ofheat recovery stream generator (HRSG), which is a heat exchanger thataccepts hot air from a storage unit, returns cooler air, and heats anexternal process fluid. The depicted OTSG is configured to use thermalenergy stored in structure 400 to generate steam at output 411.

As has been described, thermal storage structure 400 includes outerstructure 401 such walls, a roof, as well as thermal storage 403 in afirst section of the structure. The OTSG is located in a second sectionof the structure, which is separated from the first section by thermalbarrier 425. During a charging mode, thermal energy is stored in thermalstorage 403. During a discharging mode, the thermal energy stored inthermal storage 403 receives a fluid flow (e.g., air) by way of a blower405. These fluid flows may be generated from fluid entering structure400 via an inlet valve 419, and include a first fluid flow 412A (whichmay be directed to a first stack within thermal storage 403) and asecond fluid flow 412B (which may be directed to a second stack withinthermal storage 403).

As the air or other fluid directed by blower 405 flows through thethermal storage 403 from the lower portion to the upper portion, it isheated and is eventually output at the upper portion of thermal storage403. The heated air, which may be mixed at some times with a bypassfluid flow 412C that has not passed through thermal storage 402, ispassed over a conduit 409 through which flows water or another fluidpumped by the water pump 407. In one implementation, the conduit forms along path with multiple turns, as discussed further in connection withFIG. 5 below. As the hot air heats up the water in the conduit, steam isgenerated at 411. The cooled air that has crossed the conduit (andtransferred heat to the water flowing through it) is then fed back intothe brick heat storage 403 by blower 405. As explained below, thecontrol system can be configured to control attributes of the steam,including steam quality, or fraction of the steam in the vapor phase,and flow rate.

As shown in FIG. 4 , an OTSG does not include a recirculating drumboiler. Properties of steam produced by an OTSG are generally moredifficult to control than those of steam produced by a more traditionalHRSG with a drum, or reservoir. The steam drum in such an HRSG acts as aphase separator for the steam being produced in one or more heated tubesrecirculating the water; water collects at the bottom of the reservoirwhile the steam rises to the top. Saturated steam (having a steamquality of 100%) can be collected from the top of the drum and can berun through an additional heated tube structure to superheat it andfurther assure high steam quality. Drum-type HRSGs are widely used forpower plants and other applications in which the water circulatingthrough the steam generator is highly purified and stays clean in aclosed system. For applications in which the water has significantmineral content, however, mineral deposits form in the drum and tubesand tend to clog the system, making a recirculating drum designinfeasible.

For applications using water with a higher mineral content, an OTSG maybe a better option. One such application is oil extraction, in whichfeed water for a steam generator may be reclaimed from a water/oilmixture produced by a well. Even after filtering and softening, suchwater may have condensed solid concentrations on the order of 10,000 ppmor higher. The lack of recirculation in an OTSG enables operation in amode to reduce mineral deposit formation; however, an OTSG needs to beoperated carefully in some implementations to avoid mineral deposits inthe OTSG water conduit. For example, having some fraction of waterdroplets present in the steam as it travels through the OTSG conduit maybe required to prevent mineral deposits by retaining the minerals insolution in the water droplets. This consideration suggests that thesteam quality (vapor fraction) of steam within the conduit must bemaintained below a specified level. On the other hand, a high steamquality at the output of the OTSG may be important for the processemploying the steam. Therefore, it is advantageous for a steam generatorpowered by VRE through TES to maintain close tolerances on outlet steamquality. There is a sensitive interplay among variables such as inputwater temperature, input water flow rate and heat input, which must bemanaged to achieve a specified steam quality of output steam whileavoiding damage to the OTSG.

Implementations of the thermal energy storage system disclosed hereinprovide a controlled and specified source of heat to an OTSG. Thecontrolled temperature and flow rate available from the thermal energystorage system allows effective feed-forward and feedback control of thesteam quality of the OTSG output. In one implementation, feed-forwardcontrol includes using a target steam delivery rate and steam qualityvalue, along with measured water temperature at the input to the waterconduit of the OTSG, to determine a heat delivery rate required by thethermal energy storage system for achieving the target values. In thisimplementation, the control system can provide a control signal tocommand the thermal storage structure to deliver the flowing gas acrossthe OTSG at the determined rate. In one implementation, a thermal energystorage system integrated with an OTSG includes instrumentation formeasurement of the input water temperature to the OTSG.

In one implementation, feedback control includes measuring a steamquality value for the steam produced at the outlet of the OTSG, and acontroller using that value to adjust the operation of the system toreturn the steam quality to a desired value. Obtaining the outlet steamquality value may include separating the steam into its liquid and vaporphases and independently monitoring the heat of the phases to determinethe vapor phase fraction. Alternatively, obtaining the outlet steamquality value may include measuring the pressure and velocity of theoutlet steam flow and the pressure and velocity of the inlet water flow,and using the relationship between values to calculate an approximationof the steam quality. Based on the steam quality value, a flow rate ofthe outlet fluid delivered by the thermal storage to the OTSG may beadjusted to achieve or maintain the target steam quality. In oneimplementation, the flow rate of the outlet fluid is adjusted byproviding a feedback signal to a controllable element of the thermalstorage system. The controllable element may be an element used inmoving fluid through the storage medium, such as a blower or other fluidmoving device, a louver, or a valve.

The steam quality measurement of the outlet taken in real time may beused as feedback by the control system to determine the desired rate ofheat delivery to the OTSG. To accomplish this, an implementation of athermal energy storage system integrated with an OTSG may includeinstruments to measure inlet water velocity and outlet steam flowvelocity, and, optionally, a separator along with instruments forproviding separate measurements of the liquid and vapor heat values. Insome implementations, the tubing in an OTSG is arranged such that thetubing closest to the water inlet is positioned in the lowesttemperature portion of the airflow, and that the tubing closest to thesteam exit is positioned in the highest temperature portion of theairflow. In some implementations of the present innovations, the OTSGmay instead be configured such that the highest steam quality tubes(closest to the steam outlet) are positioned at some point midwaythrough the tubing arrangement, so as to enable higher inlet fluidtemperatures from the TSU to the OTSG while mitigating scale formationwithin the tubes and overheating of the tubes, while maintaining propersteam quality. The specified flow parameters of the heated fluidproduced by thermal energy storage systems as disclosed herein may insome implementations allow precise modeling of heat transfer as afunction of position along the conduit. Such modeling may allow specificdesign of conduit geometries to achieve a specified steam qualityprofile along the conduit.

FIG. 5 illustrates a cross-section of the piping of an OTSG 490.Continuous serpentine piping 495 is provided having multiple bends, andturnarounds at the end of each piping row. As shown, the flow within thepipe 495 passes through the OTSG and turns around, laterally across arow, and then moves upward one row at a time. The pipe 495 has a smallerdiameter near the inlet and a larger diameter in the sections nearer theoutlet. The increase in diameter is to enable adequate linear flowvelocity of the cooler inlet fluid, which is smaller in volume andhigher in viscosity, to enable effective heat transfer, and compensatefor the expansion of steam without excessive flow velocities in thelater tubing sections. In one implementation, the diameter is changed ina discrete manner, and in another the diameter of the piping may taperfrom a smaller diameter at the input to larger diameter at the output,or some combination of these two designs, such as a smaller-diametertapered portion coupled to a larger, fixed-diameter portion of the pipe495. Openable ports may be provided at the inlet and the outlet of theserpentine tubing to enable the effective introduction, passage andremoval of cleaning tools, or “pigs,” periodically driven through thepiping to remove any internal deposits. It is beneficial for suchcleaning or “pigging” for a tubing section being pigged to be ofapproximately constant inner diameter. Accordingly, openable ports maybe positioned at the points where tubing diameter changes so as toenable the effective introduction and removal of pigs of sizesappropriate to each tubing diameter section during pigging operations.

As shown in FIG. 6 , the output of the thermal energy storage system maybe used for an integrated cogeneration system 500. As previouslyexplained, an energy source 501 provides electrical energy that isstored as heat in the heat storage 503 of the TSU. During discharge, theheated air is output at 505. As shown in FIG. 6 , lines containing afluid, in this case water, are pumped into a drum 506 of an HRSG 509 viaa preheating section of tubing 522. In this implementation, HRSG 509 isa recirculating drum type steam generator, including a drum or boiler506 and a recirculating evaporator section 508. The output steam passesthrough line 507 to a superheater coil, and is then provided to aturbine at 515, which generates electricity at 517. As an output, theremaining steam 521 may be expelled to be used as a heat source for aprocess, or condensed at 519 and optionally passed through to adeaeration unit 513 and delivered to pump 511 in order to performsubsequent steam generation.

Certain industrial applications may be particularly well-suited forcogeneration. For example, some applications use higher temperature heatin a first system, such as to convert the heat to mechanical motion asin the case of a turbine, and lower-temperature heat discharged by thefirst system for a second purpose, in a cascading manner; or an inversetemperature cascade may be employed. One example involves a steamgenerator that makes high-pressure steam to drive a steam turbine thatextracts energy from the steam, and low-pressure steam that is used in aprocess, such as an ethanol refinery, to drive distillation and electricpower to run pumps. Still another example involves a thermal energystorage system in which hot gas is output to a turbine, and the heat ofthe turbine outlet gas is used to preheat inlet water to a boiler forprocessing heat in another steam generator (e.g., for use in an oilfieldindustrial application). In one application, cogeneration involves theuse of hot gas at e.g. 840° C. to power or co-power hydrogenelectrolysis, and the lower temperature output gas of the hydrogenelectrolyzer, which may be at about 640° C., is delivered alone or incombination with higher-temperature heat from a TSU to a steam generatoror a turbine for a second use. In another application, cogenerationinvolves the supply of heated gas at a first temperature e.g. 640° C. toenable the operation of a fuel cell, and the waste heat from the fuelcell which may be above 800° C. is delivered to a steam generator or aturbine for a second use, either alone or in combination with other heatsupplied from a TSU.

A cogeneration system may include a heat exchange apparatus thatreceives the discharged output of the thermal storage unit and generatessteam. Alternately, the system may heat another fluid such assupercritical carbon dioxide by circulating high-temperature air fromthe system through a series of pipes carrying a fluid, such as water orCO₂, (which transfers heat from the high-temperature air to the pipesand the fluid), and then recirculating the cooled air back as an inputto the thermal storage structure. This heat exchange apparatus is anHRSG, and in one implementation is integrated into a section of thehousing that is separated from the thermal storage.

The HRSG may be physically contained within the thermal storagestructure, or may be packaged in a separate structure with ductsconveying air to and from the HRSG. The HRSG can include a conduit atleast partially disposed within the second section of the housing. Inone implementation, the conduit can be made of thermally conductivematerial and be arranged so that fluid flows in a “once-through”configuration in a sequence of tubes, entering as lower-temperaturefluid and exiting as higher temperature, possibly partially evaporated,two-phase flow. As noted above, once-through flow is beneficial, forexample, in processing feedwater with substantial dissolved mineralcontaminants to prevent accumulation and precipitation within theconduits.

In an OTSG implementation, a first end of the conduit can be fluidicallycoupled to a water source. The system may provide for inflow of thefluids from the water source into a first end of the conduit, and enableoutflow of the received fluid or steam from a second end of the conduit.The system can include one or more pumps configured to facilitate inflowand outflow of the fluid through the conduit. The system can include aset of valves configured to facilitate controlled outflow of steam fromthe second end of the conduit to a second location for one or moreindustrial applications or electrical power generation. As shown in FIG.6 , an HRSG may also be organized as a recirculating drum-type boilerwith an economizer and optional superheater, for the delivery ofsaturated or superheated steam.

The output of the steam generator may be provided for one or moreindustrial uses. For example, steam may be provided to a turbinegenerator that outputs electricity for use as retail local power. Thecontrol system may receive information associated with local powerdemands, and determine the amount of steam to provide to the turbine, sothat local power demands can be met.

In some implementations, the “hybrid” or joint supply of steam orprocess heat from a thermal storage unit powered by VRE and aconventional furnace or boiler powered by fossil fuel is beneficial.FIG. 97 discloses a system 9900 where a fuel-fired heater 9905 (furnace,boiler, or HRSG) supplies heat in the form of a first flow of hot gas orsteam to a use 9909 (e.g. A turbine, an oilfield, a factory), and athermal storage unit 9901 powered by VRE or intermittent grid powerprovides heat in the form of a second flow of hot gas or steam to theuse. The two sources—fuel-powered (9905) and VRE-powered (9907)—may befluidically connected to a common supply inlet 9907 of air, CO₂, salt,oil, or water to be heated, and fluidically connected to a common outletor use of heated fluid or steam.

A controller 9903 may control or partially control the operation of thefuel-fired heater 9905 and the VRE storage heater 9901, with inputs tothe controller including information derived from forecasts of weather9910, the pricing and availability of electricity 9911, the pricing andavailability of fuel 9911, the state of charge of the TSU 9915, thereadiness and state of the equipment 9913, and the current and plannedenergy requirements of the connected load 9914. The controller mayschedule and control the operation of TSU charging, fuel combustion, andTSU output in a means to meet the needs of the use at the lowestpossible CO₂ emissions and/or the lowest total operating cost.

In addition to the generation of electricity, the output of the thermalstorage structure may be used for industrial applications as explainedbelow. Some of these applications may include, but are not limited to,electrolyzers, fuel cells, gas generation units such as hydrogen, carboncapture, manufacture of materials such as cement, calciningapplications, as well as others. More details of these industrialapplications are provided further below.

Thermal Storage Structure

FIG. 7 illustrates an isometric view 700 of one implementation of athermal storage structure 701, which is an implementation of thermalstorage structure 12 depicted in FIG. 1 . More specifically, structure701 includes a roof 703, sidewalls 705, and a foundation 707. As shownat 709, a blower is provided that may draw air in and out fortemperature regulation and safety. At 711, a housing is shown that mayhouse the blower, steam generation unit, and/or other equipmentassociated with an input or an output to structure 701.

Further, switchgear or other electrical and electronic equipment may beinstalled at thermal storage structure 701. This is made possible due tothe dynamic insulation, which reduces the heat that is transferred tothe outer surface of structure 701, which in turn allows for equipmenthaving a limited temperature operating range to be positioned there.Such equipment may include sensors, telecommunication devices,controllers, or other equipment required to operate structure 701.

FIG. 8 illustrates a perspective view 800 of a thermal storage structure801. As shown above, the plenum near 803 and sidewalls 805 are shown.The inside of the roof includes insulation 807. At 809, the housing maycontain the exhaust or blower as explained above. As shown at 811, thepassages between the stacks of structure 801 and the outer surface ofthe sidewalls 805 may be provided as a vertically slotted chamber. Suchvertical slots are optional, however, and other configurations may beused, including a configuration that has no slots and forms a chamber.As explained above, the cool air is provided by the blower to a gapbetween the bricks and the insulation 807, and subsequently flows downthe walls of structure 801 to the plenum near 803, where the cool air iswarmed by heat from the stacks of bricks as it passes between the stacksof bricks and the insulation 807, and out to a steam generator 813, forexample. The somewhat warmed air flows through air flow paths in thestacks of bricks, from below. Further, element 809 may also include theblower. Finally, the system may be an open-loop, as opposed to aclosed-loop, configuration. This means, for example, that intake ambientair instead of recirculating air from the industrial application may beused.

FIG. 9 illustrates a top view 900 of the inner roof of a thermal storagestructure 901 according to an example implementation. As explainedabove, an insulating layer 903 surrounds the hot bricks, and provides aheat barrier between the output of the stacks of bricks and the outerstructure of the thermal storage structure 901. The incoming air, whichmay be driven by a blower (such as one in air exchange device 905),flows through the sidewalls to the plenum at the base of foundation 911.Also shown is the slotted portion 907 and the steam generator 909, asexplained above. As used in the present disclosure, “cool” air refers toair that is cooler than the discharge air when the TSU is charged,though it may be in fact quite warm, e.g. around 200° C. or more, in thecase of return air from a process, or it may be cooler,ambient-temperature outdoor air in the case of air provided from theenvironment surrounding the thermal storage unit; or at some temperaturebetween these ranges, depending upon the source of the “cool” air.

FIG. 10 illustrates a bottom portion 1000 under the stack of bricks.Once the fluid arrives at the bottom of the thermal storage structuredescribed above with respect to FIG. 9 , it flows from the edges 1003lengthwise through channels to a region 1001 underneath the stack ofbricks. This fluid, which is significantly cooler than the temperatureof the top of the stack when the stack is charged, cools the foundationand the exterior and provides an insulative layer between the stack andthe surrounding structure including the foundation, and thus reducesheat losses and allows the use of inexpensive, ordinary insulationmaterials. This prevents heat damage to the surrounding structure andfoundation.

FIG. 11 illustrates an isometric view 1100 of a thermal storagestructure. As shown, a seismic reinforcing structure 1101 is provided onthe outside of an outer surface of the entire structure. The structure1103, which may house an air exchange device or other equipment asexplained above, is formed on top of the seismic reinforcing structure1101. As shown in 1105, an insulated layer is formed above the stacks ofbricks, leaving an air gap for dynamic insulation for the cool air.Sidewalls 1107, foundation 1109, slotted portion 1113 and steamgenerator 1111 are also included.

Additionally, one or more base isolators 1115 (which may include elasticand/or plastic deformation materials which may act respectively assprings and as energy absorbers) may be provided below the foundationthat reduce the peak forces experienced during seismic events. In someimplementations, the base isolator may reduce the peak force in anearthquake such that 10% or less of the force from the earthquake istransferred to the structures above the base isolator. The abovepercentages may vary as a function of relative motion between the groundand base isolator. Just as an example, the thermal energy storagestructure may include a space of 45 cm to 60 cm between the ground andthe slab to reduce the g-forces transmitted to stack by 90%. Byproviding the seismic reinforcing structure 1101, the thermal storagestructure may be more safely operated in earthquake-prone regions.

FIG. 12 illustrates an isometric view 1200 of a support structure forbricks in a thermal storage structure according to an exampleimplementation. A foundation 1201, shown as beams attached to oneanother, forms a base upon which stacks of bricks may be positioned.Structures 1203 a, 1203 b form a support for the bricks. A verticalsupport 1207, which may directly interface with the bricks, and asupport beam 1205 provide additional support.

FIG. 13 illustrates views 1300 of additional structures that may beassociated with a thermal storage structure. For example, a blower 1301receives air and blows it into the structure. As explained above, theair may, in some cases, be cooled air that has passed through the steamgenerator. At 1303, louvers are illustrated, which may control the inletair flowing into the thermal storage elements. Such louvers may bepositioned so as to selectively adjust the flow of air through regionsof the TSU so as to adjust the discharge of high-temperature air whilebeing positioned in flows of lower-temperature air. Such louvers mayincorporate fail-safe controls that set the louvers to a pre-determinedposition upon the failure of a control system, an actuator, or a supplyof electric power, by actuation means that may include springs, weights,compressed air, materials that change dimensions with temperature,and/or other means.

Dynamic Insulation

It is generally beneficial for a thermal storage structure to minimizeits total energy losses via effective insulation, and to minimize itscost of insulation. Some insulation materials are tolerant of highertemperatures than others. Higher-temperature tolerant materials tend tobe more costly.

FIG. 14 provides a schematic section illustration 1400 of animplementation of dynamic insulation. Note that while the followingdiscussion of FIG. 14 provides an introduction to dynamic insulationtechniques and passive cooling, more detailed examples are providedbelow with reference to FIGS. 57 through 62 .

The outer container includes roof 1401, walls 1403, 1407 and afoundation 1409. Within the outer container, a layer of insulation 1411is provided between the outer container and columns of bricks in thestack 1413, the columns being represented as 1413 a, 1413 b, 1413 c,1413 d and 1413 e. The heated fluid that is discharged from the upperportion of the columns of bricks 1413 a, 1413 b, 1413 c, 1413 d and 1413e exits by way of an output 1415, which is connected to a duct 1417. Theduct 1417 provides the heated fluid as an input to a steam generator1419. Once the heated fluid has passed through the steam generator 1419,some of its heat is transferred to the water in the steam generator andthe stream of fluid is cooler than when exiting the steam generator.Cooler recycled fluid exits a bottom portion 1421 of the steam generator1419. An air blower 1423 receives the cooler fluid, and provides thecooler fluid, via a passage 1425 defined between the walls 1403 andinsulation 1427 positioned adjacent the stack 1413, through an upper airpassage 1429 defined between the insulation 1411 and the roof 1401, downthrough side passages 1431 defined on one or more sides of the stack1413 and the insulation 1411, and thence down to a passage 1433 directlybelow the stack 1413.

The air in the passages 1425, 1429, 1431 and 1433 acts as an insulatinglayer between (a) the insulations 1411 and 1427 surrounding the stack1413, and (b) the roof 1401, walls 1403, 1407 and foundation 1409. Thus,heat from the stack 1413 is prevented from overheating the roof 1401,walls 1403, 1407 and foundation 1409. At the same time, the air flowingthrough those passages 1425, 1429, 1431 and 1433 carries by convectionheat that may penetrate the insulations 1411 and/or 1417 into air flowpassages 1435 of the stack 1413, thus preheating the air, which is thenheated by passage through the air flow passages 1435.

The columns of bricks 1413 a, 1413 b, 1413 c, 1413 d and 1413 e and theair passages 1435 are shown schematically in FIG. 14 . The physicalstructure of the stacks and air flow passages therethrough inembodiments described herein is more complex, leading to advantages asdescribed below.

In some implementations, to reduce or minimize the total energy loss,the layer of insulation 1411 is a high-temperature primary insulationthat surrounds the columns 1413 a, 1413 b, 1413 c, 1413 d and 1413 ewithin the housing. Outer layers of lower-cost insulation may also beprovided. The primary insulation may be made of thermally insulatingmaterials selected from any combination of refractory bricks, aluminafiber, ceramic fiber, and fiberglass or any other material that might beapparent to a person of ordinary skill in the art. The amount ofinsulation required to achieve low losses may be large, given the hightemperature differences between the storage media and the environment.To reduce energy losses and insulation costs, conduits are arranged todirect returning, cooler fluid from the HRSG along the outside of aprimary insulation layer before it flows into the storage core forreheating.

The cooler plenum, including the passages 1425, 1429, 1431 and 1433, isinsulated from the outside environment, but total temperaturedifferences between the cooler plenum and the outside environment arereduced, which in turn reduces thermal losses. This technique, known as“dynamic insulation,” uses the cooler returning fluid, as describedabove, to recapture heat which passes through the primary insulation,preheating the cooler air before it flows into the stacks of the storageunit. This approach further serves to maintain design temperatureswithin the foundation and supports of the thermal storage structure.Requirements for foundation cooling in existing designs (e.g., formolten salt) involve expensive dedicated blowers andgenerators—requirements avoided by implementations according to thepresent teaching.

The materials of construction and the ground below the storage unit maynot be able to tolerate high temperatures, and in the present systemactive cooling—aided by the unassisted flowing heat exchange fluid inthe case of power failure—can maintain temperatures within designlimits.

A portion of the fluid returning from the HRSG may be directed throughconduits such as element 1421 located within the supports and foundationelements, cooling them and delivering the captured heat back to theinput of the storage unit stacks as preheated fluid. The dynamicinsulation may be provided by arranging the bricks 1413 a, 1413 b, 1413c, 1413 d and 1413 e within the housing so that the bricks 1413 a, 1413b, 1413 c, 1413 d and 1413 e are not in contact with the outer surface1401, 1403, 1407 of the housing, and are thus thermally isolated fromthe housing by the primary insulation formed by the layer of cool fluid.The bricks 1413 a, 1413 b, 1413 c, 1413 d and 1413 e may be positionedat an elevated height from the bottom of the housing, using a platformmade of thermally insulating material.

During unit operation, a controlled flow of relatively cool fluid isprovided by the fluid blowing units 1423, to a region (includingpassages 1425, 1429, 1431 and 1433) between the housing and the primaryinsulation (which may be located on an interior or exterior of an innerenclosure for one or more thermal storage assemblages), to create thedynamic thermal insulation between the housing and the bricks, whichrestricts the dissipation of thermal energy being generated by theheating elements and/or stored by the bricks into the outsideenvironment or the housing, and preheats the fluid. As a result, thecontrolled flow of cold fluid by the fluid blowing units of the systemmay facilitate controlled transfer of thermal energy from the bricks tothe conduit, and also facilitates dynamic thermal insulation, therebymaking the system efficient and economical.

In another example implementation, the buoyancy of fluid can enable anunassisted flow of the cold fluid around the bricks between the housingand the primary insulator 1411 such that the cold fluid may providedynamic insulation passively, even when the fluid blowing units 1423fail to operate in case of power or mechanical failure, therebymaintaining the temperature of the system within predefined safetylimits, to achieve intrinsic safety. The opening of vents, ports, orlouvres (not shown) may establish passive buoyancy-driven flow tomaintain such flow, including cooling for supports and foundationcooling, during such power outages or unit failures, without the needfor active equipment. These features are described in greater detailbelow in connection with FIGS. 58-62 .

In the above-described fluid flow, the fluid flows to an upper portionof the unit, down the walls and into the inlet of the stacking,depending on the overall surface area to volume ratio, which is in turndependent on the overall unit size, the flow path of the dynamicinsulation may be changed. For example, in the case of smaller unitsthat have greater surface area as compared with the volume, the amountof fluid flowing through the stack relative to the area may utilize aflow pattern that includes a series of serpentine channels, such thatthe fluid flows on the outside, moves down the wall, up the wall, anddown the wall again before flowing into the inlet. Other channelizationpatterns may also be used.

Additionally, the pressure difference between the return fluid in theinsulation layer and the fluid in the stacks may be maintained such thatthe dynamic insulation layer has a substantially higher pressure thanthe pressure in the stacks themselves. Thus, if there is a leak betweenthe stacks and the insulation, the return fluid at the higher pressuremay be forced into the leak or the cracks, rather than the fluid withinthe stacks leaking out into the dynamic insulation layer. Accordingly,in the event of a leak in the stacks, the very hot fluid of the stacksmay not escape outside of the unit, but instead the return fluid maypush into the stacks, until the pressure between the dynamic insulationlayer in the stacks equalizes. Pressure sensors may be located on eitherside of the blower that provide relative and absolute pressureinformation. With such a configuration, a pressure drop within thesystem may be detected, which can be used to locate the leak.

Earlier systems that store high temperature sensible heat in rocks andmolten salts have required continuous active means of coolingfoundations, and in some implementations continuous active means ofheating system elements to prevent damage to the storage system; thus,continuous active power and backup power supply systems are required. Asystem as described herein does not require an external energy supply tomaintain the safety of the unit. Instead, as described below, thepresent disclosure provides a thermal storage structure that providesfor thermally induced flows that passively cools key elements whenequipment, power, or water fails. This also reduces the need for fans orother cooling elements inside the thermal storage structure.

Control System

The operation of a thermal storage unit as described herein can beoptimized based on factors such as the lifetime of the components(heaters, bricks, structure, electronics, fans, etc.), requiredtemperature and duration of output heat, availability of energy sourceand cost, among other factors. In some instances, the components exposedto high temperature are limited, using dynamic insulation to reducetemperatures of foundation, walls, etc.).

The control system may use feedback from computer models, weatherpredictions and sensors such as temperature and airflow to optimize longterm performance. In particular, rates of heating and cooling as well asduration at peak temperature can have a detrimental effect on thelifetime of heating elements, bricks and other components. As physicalproperties of the components and airflow patterns, for example, maychange as they age, feedback can be used to inform an artificialintelligence (AI) system to continue to provide high performance foryears. Examples of such evolving physical properties and data reflectingsuch changes may include changing resistance of the heater elements,failure of heaters, changes in airflow behavior, and changes in heattransfer in bricks due to cracks or other damage.

An operational mode that reduces exposure to peak temperature can usedata from models, weather predictions, sensors and time of year andlocation information to intelligently tune charging rates and extent.For example, during peak photovoltaic (PV) production days of summer,the days are relatively long and dark hours are relatively short. If theweather prediction expects multiple sunny days in a row, the thermalstorage unit does not need to be charged to a high degree in order forthe storage to serve the customer's needs during dark hours. In such anexample case, reducing the charging extent and peak temperature reducesthe stress on the system so that service life is increased.

Example implementations of the present disclosure may include a smartenergy storage controller system 300 as described above with respect toFIG. 3 . The system 300 monitors and receives information associateswith local parameters such as wind, solar radiation, and passing clouds.The system 300 can also be configured to receive any one or more ofnetwork-supplied hourly and multiday forecasts of weather, forecast andcurrent availability and cost of VRE and/or other available energysources, forecast and current energy demand of load. This includesinformation on industrial process requirements, current and forecastprices of energy, contractual or regulatory requirements to maintain aminimum state of charge to participate in capacity or resource adequacytransactions and markets. The system 300 further include state of chargeand temperature of subsections of the storage media.

FIG. 15 is a block diagram illustrating one implementation of variouscontrol systems that may be located throughout the system 300. As shown,system 1500 includes several constituent control systems configured tocontrol different portions of distributed control system 300. Thesecontrol systems include thermal storage control system 1502, applicationcontrol system 1504, power source control system 1506 and externalanalysis system 1508. Constituent control systems in system 1500 areinterconnected using communication links such as 1501, 1503 and 1505.Links 1501, 1503 and 1505 may be wired, wireless, or combinationsthereof. Other implementations of a control system for thermal energystorage and distribution may include different combinations and types ofconstituent control systems.

Thermal storage control system 1502 is configured to control a thermalenergy storage system such as those that have been disclosed herein, andmay be an implementation of control system 15 depicted in FIG. 1 .Elements controlled by system 1502 may include, without limitation,switches, valves, louvers, heating elements and blowers associated withthermal storage assemblages, including switches for connecting inputenergy from energy sources such as a solar field or wind farm. Controlsystem 1502 is configured to receive information from various sensorsand communication devices within the thermal energy storage system,providing information on parameters that may include state of thermalenergy charge, temperature, valve or louver position, fluid flow rate,information about remaining lifetime of components, etc. Control system1502 may then control system operation based on these parameters. In oneimplementation, control system 1502 may be configured to control aspectsof the upstream energy source and/or the downstream application system.

Power source control system 1506 is configured to control aspects of theenergy source for the thermal storage system. In one implementation, theenergy source is a source of variable renewable electricity such as afield of photovoltaic panels (“solar field”) or a wind turbine farm.Systems 1502 and 1506 are configured to communicate with one another toexchange control information and data, including data relating to theoperational status of the thermal energy storage system or energysource, input energy requirements of the thermal energy storage system,predicted future output of the energy source, etc. In oneimplementation, control system 1506 may be configured to control one ormore aspects of the thermal energy storage system relevant to operationof the energy source.

Application control system 1504 is configured to control aspects of asystem receiving output energy from the thermal energy storage systemcontrolled by system 1502. Systems 1502 and 1504 are configured tocommunicate with one another to exchange control information and data,including data relating to the operational status of the thermal energystorage system or application system, amount of energy output from thethermal storage system needed by the application system, predictedfuture energy output from the thermal storage system, etc. In oneimplementation, control system 1504 may be configured to control one ormore aspects of the thermal energy storage system relevant to operationof the application system.

External analytics system 1508 is configured, in one implementation, toobtain and analyze data relevant to operation of one or more of systems1502, 1504 and 1506. In one implementation, system 1508 is configured toanalyze forecast information such as weather information or energymarket information and generate predictions regarding availability orcost of input power to thermal storage control system 1502. System 1508may then communicate with thermal storage control system 1502 over link1503 in order to convey information and/or commands, which may then beimplemented by system 1502 and/or systems 1506 and 1504.

FIG. 16 is a block diagram illustrating one implementation of thermalstorage control system 1502. As shown, system 1502 includes a processor1510, memory 1512, data storage 1514 and communications interface 1516.Processor 1510 is a processor configured to execute programs stored inmemory 1512, such as control programs 1518 for managing the operation ofone or more thermal storage arrays similar to those described herein. InFIG. 16 , memory 1512 is shown as being located within processor 1510,but in other implementations external memory or a combination ofinternal and external memory is possible. Control programs 1518 mayinclude a variety of programs, including those for sending signals tovarious elements associated with a thermal storage structure, such asswitches for heater elements, louvers, blowers, valves for directing andadjusting gas flows, etc. Execution of control programs 1518 can thuseffectuate various modes of operation of the thermal storage system,including charging and discharging, as well as coordinated operation ofmultiple thermal storage arrays to maintain a specified temperatureprofile (e.g., a constant temperature or a non-constant predefinedtemperature schedule).

Two potential types of control are sensor-based control and model-basedcontrol. In a sensor-based control paradigm, readings from sensorsplaced throughout system 1500 may be used to determine real-time valuesthat correspond to actual measurements. Thermal storage structuresaccording to this disclosure may be designed in order to limit theexposure of certain components to high, thereby improving reliability.But the use of sensors, while potentially representing the most accuratepossible state of system 1500, may be expensive, and also may be proneto malfunction if sensors fail. A model-based control paradigm, on theother hand, provides the ability to control a large complex system withless expense than that associated with deploying a multitude of sensors,and to minimize safety risks that might be associated with undetectedsensor failure. A modeling program 1520 within memory 1512 may thus beused to model and predict behavior of the thermal energy storage systemover a range of input parameters and operational modes. Control system1502 may also be configured to combine model-based and sensor-basedcontrol of the thermal energy storage system—which may allow forredundancy as well as flexibility in operation. Other programs may alsobe stored in memory 1512 in some implementations, such as a userinterface program that allows for system administration.

Data storage 1514 can take any suitable form, including semiconductormemory, magnetic or optical disk storage, or solid-state drives. Datastorage 1514 is configured to store data used by system 1502 incontrolling the operation of the thermal storage system, includingsystem data 1522 and historical data 1524. In one implementation, systemdata 1522 describes the configuration or composition of elements of theone or more thermal storage arrays being controlled. Examples ofpossible system data include shape or composition of bricks within athermal storage assemblage, composition of heating elements integratedwith an assemblage, and the number of thermal storage assemblages in thethermal storage system. Historical data 1524 may include data collectedover time as the thermal storage system is operated, as well as datafrom other units in some cases. Data 1524 may include system log data,peak heater temperatures, peak output gas temperatures, discharge ratesof a thermal storage assemblage, a number of heating and cooling cyclesfor an assemblage, etc.

Communications interface 1516 is configured to communicate with othersystems and devices, such as by sending and receiving data and signalsbetween system 1502 and control systems 1504 and 1506, or between system1502 and external analysis system 1508. Interface 1516 is alsoconfigured to send control signals to controlled elements of the thermalstorage system, and receive sensor signals from sensors for the controlsystem, such as sensors 303-1 through 303-N of FIG. 1 . Although shownas a single interface for simplicity, interface 1516 may includemultiple communications interfaces (e.g., both wired and wireless).Control systems 1502, 1504 and 1506 as illustrated in FIGS. 15 and 16may be implemented in various ways, including using a general-purposecomputer system. Systems 1502, 1504 and 1506 may also be implemented asprogrammable logic controllers (PLCs) or computer systems adapted forindustrial process control. In some cases, systems 1502, 1504 and 1506are implemented within a distributed control system architecture such asa Supervisory Control and Data Acquisition (SCADA) architecture.

FIG. 17 is a block diagram illustrating an implementation of externalanalytics system 1508. System 1508 is configured to provideforecast-based predictions to thermal storage control system 1502.System 1508 includes a processor 1530, memory 1532, data storage 1534and communications interface 1536. In one implementation, system 1508 isimplemented in a distributed computing environment such as a cloudcomputing environment. A cloud computing environment is advantageous inallowing computing power and data storage to be increased on demand toperform intensive analysis of copious amounts of data to provide timelypredictions.

Processor 1530 is a processor configured to execute programs stored inmemory 1532, such as supply forecast program 1538, maintenance forecastprogram 1540, market forecast program 1542 and predictive analyticsprogram 1520. Supply forecast program 1538 includes instructionsexecutable to use weather forecast data and predictive analytics methodsto predict power supply availability to the thermal energy storagesystem. Maintenance forecast program 1540 includes instructionsexecutable to use system data and predictive analytics methods topredict maintenance requirements for the thermal energy storage system.Market forecast program 1542 includes instructions executable to usepower market data and predictive analytics methods to predict powerpricing values or trends for power used by or produced by the thermalenergy storage system. Predictive analytics 1520 includes instructionsexecutable to implement algorithms for analyzing data to makepredictions. Algorithms within predictive analytics 1520 are used byprograms 1538, 1540 and 1542.

Data storage 1534 stores data including weather data 1546, market data1548, supply data 1550, thermal storage (TS) data 1552, and application(App.) data 1554. Data stored in data storage 1534 may be used byprograms stored in memory 1532. Weather data 1546 may include datacollected at the location of the power source for the thermal energystorage system along with broader-area weather information obtained fromdatabases. Market data 1548 includes energy market data received fromexternal data providers. Supply data 1550 includes data associated withthe power source controlled by system 1506, and may include, forexample, system configuration data and historical operations data. TSdata 1552 includes data associated with the thermal energy storagesystem, and application data 1554 includes data associated with theapplication system controlled by control system 1504. Communicationsinterface 1536 is configured to send data and messages to and fromsystem 1502 as well as external databases and data sources.

Systems and components shown separately in FIGS. 15 through 17 may inother implementations be combined or be separated into multipleelements. For example, in an implementation for which an applicationsystem like a steam generator is closely connected with a thermal energystorage system, aspects of control systems 1502 and 1504 may be combinedin the same system. Data and programs may be stored in different partsof the system in some implementations; a data collection or programshown as being stored in memory may instead be stored in data storage,or vice versa.

In other scenarios, systems 1502 or 1508 may contain fewer program anddata types than shown in FIGS. 16 and 17 . For example, oneimplementation of analytics system 1508 may be dedicated toenergy-supply forecasting using weather data, while anotherimplementation is dedicated to power market forecasting using marketdata, and still another implementation is dedicated to maintenanceforecasting using system-related data. Other implementations ofanalytics system 1508 may include combinations of two of the threeprogram types shown in FIG. 17 , along with corresponding data typesused by those program types, as discussed above. For example, oneimplementation of system 1508 may be configured for both energy-supplyforecasting using weather data and power market forecasting using marketdata, but not for maintenance forecasting using system-related data.Another implementation of the system may be configured for both powermarket forecasting using market data and maintenance forecasting usingsystem-related data, but not for energy-supply forecasting using weatherdata. Still another implementation of system 1508 may be configured forboth energy-supply forecasting using weather data and maintenanceforecasting using system-related data, but not for power marketforecasting using market data.

Forecast-Based System Control

As noted above, forecast information such as weather predictions may beused by a control system to reduce wear and degradation of systemcomponents. Another goal of forecast-based control is to ensure adequatethermal energy production from the thermal energy storage system to theload or application system. Actions that may be taken in view offorecast information include, for example, adjustments to operatingparameters of the thermal energy storage system itself, adjustments toan amount of input energy coming into the thermal energy storage system,and actions or adjustments associated with a load system receiving anoutput of the thermal energy storage system.

Weather forecasting information can come from one or more of multiplesources. One source is a weather station at a site located with thegeneration of electrical energy, such as a solar array or photovoltaicarray, or wind turbines. The weather station may be integrated with apower generation facility, and may be operationally used for controldecisions of that facility, such as for detection of icing on windturbines. Another source is weather information from sources covering awider area, such as radar or other weather stations, which may be fedinto databases accessible to by the control system of the thermal energystorage system. Weather information covering a broader geography may beadvantageous in providing more advanced notice of changes in condition,as compared to the point source information from a weather stationlocated at the power source. Still another possible source of weatherinformation is virtual or simulated weather forecast information. Ingeneral, machine learning methods can be used to train the system,taking into account such data and modifying behavior of the system.

As an example, historical information associated with a power curve ofan energy source may be used as a predictive tool, taking into accountactual conditions, to provide forecasting of power availability andadjust control of the thermal energy storage system, both as to theamount of energy available to charge the units and the amount ofdischarge heat output available. For example, the power curveinformation may be matched with actual data to show that when the poweroutput of a photovoltaic array is decreasing, it may be indicative of acloud passing over one or more parts of the array, or cloudy weathergenerally over the region associated with the array.

Forecast-related information is used to improve the storage andgeneration of heat at the thermal energy storage system in view ofchanging conditions. For example, a forecast may assist in determiningthe amount of heat that must be stored and the rate at which heat mustbe discharged in order to provide a desired output to an industrialapplication—for instance, in the case of providing heat to a steamgenerator, to ensure a consistent quality and amount of steam, and toensure that the steam generator does not have to shut down. Thecontroller may adjust the current and future output of heat in responseto current or forecast reductions in the availability of chargingelectricity, so as to ensure across a period of future time that thestate of charge of the storage unit does not reduce so that heat outputmust be stopped. By adjusting the continuous operation of a steamgenerator to a lower rate in response to a forecasted reduction ofavailable input energy, the unit may operate continuously. The avoidanceof shutdowns and later restarts is an advantageous feature: shuttingdown and restarting a steam generator is a time-consuming process thatis costly and wasteful of energy, and potentially exposes personnel andindustrial facilities to safety risks.

The forecast, in some cases, may be indicative of an expected lowerelectricity input or some other change in electricity input pattern tothe thermal energy storage system. Accordingly, the control system maydetermine, based on the input forecast information, that the amount ofenergy that would be required by the thermal energy storage system togenerate the heat necessary to meet the demands of the steam generatoror other industrial application is lower than the amount of energyexpected to be available. In one implementation, making thisdetermination involves considering any adjustments to operation of thethermal energy storage system that may increase the amount of heat itcan produce. For example, one adjustment that may increase an amount ofheat produced by the system is to run the heating elements in a thermalstorage assemblage at a higher power than usual during periods of inputsupply availability, in order to obtain a higher temperature of theassemblage and greater amount of thermal energy stored. Such“overcharging” or “supercharging” of an assemblage, as discussed furtherbelow, may in some implementations allow sufficient output heat to beproduced through a period of lowered input energy supply. Overchargingmay increase stresses on the thermal storage medium and heater elementsof the system, thus increasing the need for maintenance and the risk ofequipment failure.

As an alternative to operational adjustments for the thermal energystorage system, or in embodiments for which such adjustments are notexpected to make up for a forecasted shortfall of input energy, actionon either the source side or the load side of the thermal energy storagesystem may be initiated by the control system. On the input side, forexample, the forecast difference between predicted and needed inputpower may be used to provide a determination, or decision-support, withrespect to sourcing input electrical energy from other sources during anupcoming time period, to provide the forecasted difference. For example,if the forecasting system determines that the amount of electricalenergy to be provided from a photovoltaic array will be 70% of theexpected amount needed over a given period of time, e.g., due to aforecast of cloudy weather, the control system may effectuate connectionto an alternative input source of electrical energy, such as windturbine, natural gas or other source, such that the thermal energystorage system receives 100% of the expected amount of energy. In animplementation of a thermal energy storage system having an electricalgrid connection available as an alternate input power source, thecontrol system may effectuate connection to the grid in response to aforecast of an input power shortfall.

In a particular implementation, forecast data may be used to determinedesired output rates for a certain number of hours or days ahead,presenting to an operator signals and information relating to expectedoperational adjustments to achieve those output rates, and providing theoperator with a mechanism to implement the output rates as determined bythe system, or alternatively to modify or override those output rates.This may be as simple as a “click to accept” feedback option provided tothe operator, a dead-man's switch that automatically implements thedetermined output rates unless overridden, and/or more detailed optionsof control parameters for the system.

On the output, or load, side of a thermal energy storage unit, variousactions may be initiated in response to a forecast-based prediction ofan input energy shortfall affecting the output heat to a load. FIG. 99illustrates a first forecast energy availability 9921 (a multi-dayforecast of available VRE) and a first controller decision of heatdelivery rate (shown as “RATE 1”, and a second, lower forecast 9923 ofmulti-day availability of VRE and a second, lower chosen heat deliveryrate (shown as “RATE 2”). In one implementation, the controller makes acurrent-day decision regarding heat delivery rate based on forecastenergy availability in the current and coming days so as to avert ashutdown on a future day. In an implementation, a control system of thethermal energy storage system may alert an operator of the loadindustrial application of the upcoming shortfall, so that a decision canbe made.

FIG. 98 illustrates the process 9930. At 9935, a multi-day chargingavailability forecast is generated based on a grid power model 9933 anda weather forecast 9931. The energy delivery rate is selected at 9937 toenable continuous output. At 9939, The controller-selected output ratemay be presented to an operator either as a notification via email, textmessage, or other indirect notification, or by a value or icon on alocal or remote screen which shows and allows adjustment of the statusand operation of the thermal energy storage unit or its associated heatuse process; and at 9941 may receive responding operator input whichaccepts, rejects, or adjusts the amount or timing of rate adjustment.The information may cause the manual or automatic adjustment at 9943 ofanother heat source that supplies heat to the same process, as shown inFIG. 97 , in such a manner as to achieve a desired overall relativelyconstant heat supply. Actions that may be taken on the load, or output,side of the thermal energy storage system include adjustment ofoperation of the load system so that it can operate with the predictedreduction in thermal energy available to it. Alternatively or inaddition, the controller may provide commands for the output to beadjusted, and/or adjust the operation of the industrial output itself tocompensate for the change in the expected available energy input, andhence the expected available output from the thermal energy storagesystem.

Another possible action in response to a forecast shortfall of inputenergy is to supplement the output from the thermal energy storagesystem with an alternate source of that output. In an implementation forwhich the heated fluid output from a thermal energy storage system isused to generate steam for an industrial process, for example, analternate source of steam could be an additional steam generator usingan alternate fuel source. The control system may provide signals toeffectuate connection of the alternate output source to the load systemin some implementations. Alternatively, the control system may send amessage, such as an instruction or alert, to an operator or controllerassociated with the load system to indicate the need for connection tothe alternate source.

In addition to ensuring sufficient output production by the thermalenergy storage system to a load, forecast information is used toautomatically control the thermal energy storage system to ensure itscontinued stable operation. For example, when a reduced amount of inputpower is predicted, the controller may in some implementations adjustthe fluid flow rate through a thermal storage assemblage to lower thedischarge rate from the assemblage so that the assemblage does notdischarge to a point where the associated thermal storage unit shutsdown.

As another example, the powering of the heater elements may be adjustedto a desired temperature for safety and efficiency, based on theforecast information. For example, if it is expected or forecast thatduring a future period, the amount of energy from the input source willbe less than the expected amount of energy, the system can be configuredto “supercharge”, i.e. heat some or all of the bricks in one or morestacks to temperatures higher than normal operation temperatures—forinstance, if the normal stack temperature is 1100° C., in case of anexpected period of lower energy input, the system can be controlled toheat up to 1300° C. or more for a selected period of time. This can beaccomplished by reducing the discharge from certain units and/or byincreasing the temperatures of the heater elements.

If the forecast indicates an extended period of reduced energy input,such as due to several days of cloudiness, the lead-lag capability ofthe system explained below may also be modified, because the issue ofhotspots and thermal runaway may be somewhat reduced due to the factthat the system will be operating at a temperature that is below thepeak temperature. Additionally, in a thermal energy storage system withmultiple thermal storage units, if the system cannot be run at fullcapacity, the controller may reduce or disable charging or completelyshut off one or more of the units based on the forecast, such that onlya subset of units are operating at full capacity, rather than have noneof the units be able to operate at full capacity.

In contrast to a situation involving a forecast of reduced power,forecast information may show that the expected electricity availabilitywill meet or exceed the expected amount of energy that is input into thethermal energy storage system. In some implementations, responses of acontrol system to a forecast of excess energy may include one or more ofadjusting operation of the thermal energy storage system to improvesystem reliability, reducing the amount of input power to the thermalstorage energy system, or increasing thermal power to the load.Adjusting operation of the thermal energy storage system may includereducing input power to its heater elements when input energy isavailable for longer periods, so that a corresponding thermal storageassemblage operates at a lower peak temperature while still deliveringsufficient thermal energy output. Such reduction in peak temperature mayincrease reliability and lifetime of the system. Excess input powersupply may allow heating elements to remain powered after a thermalstorage assemblage has already been charged with thermal energy,allowing the heating elements to directly heated fluid flowing through athermal storage assemblage without discharging the assemblage, possiblyto use provided such heated fluid to another use.

A control system of the thermal energy storage system may cause anamount of energy that is input to the system to be reduced. The energysource or the thermal energy storage system may be coupled to a largerpower grid, in which case a reduction in input energy to the thermalenergy storage system may be implemented by transferring excess energyto the power grid, e.g., when there is low demand from the system and/orhigh demand from the power grid to meet other electrical needs. In theabsence of a grid connection, a reduction in input energy may beimplemented in some implementations by curtailing production from aportion of the energy source infrastructure, such as shutting downcertain solar panels in a solar field or wind turbines at a wind farm.

Alternatively or in addition to control of the input power supply orthermal energy storage system operation parameters, a response to aforecast of an excess of input energy may be made at the output side ofthe thermal energy storage system. In an implementation for whichelectric power is produced at the output of the system (for example, byfeeding heated fluid from a thermal storage unit to a steam generator,then passing the produced steam through a turbine), excess power may betransferred to a larger power grid if a grid connection is available,thus providing energy to the grid instead of storing it as heat in thesystem. In an implementation for which the output to the load is heatedfluid, a property of the output fluid may be changed. For example, ahigher temperature and/or flow rate of output fluid may be produced. Foran implementation in which steam is produced at the output of thethermal energy storage system, a higher vapor quality of the steam maybe provided during periods of increased input energy. In someimplementations, altered output properties may provide enhancedcogeneration opportunities, through cogeneration systems and methodsdescribed elsewhere in this disclosure. The input and output controldescribed above may be interactively controlled in combination, toadvantageously adjust the operation of the system.

Thus, the controller can use inputs from the forecasting system toaccount for variations in input energy due to factors such as cloudinessin the case of solar energy, variability in wind conditions for windgenerated electricity, or other variability in conditions at the powersource. For example, the controller may allow for additional heating, orheating at a higher temperature, prior to a decrease in the forecastavailability of input of electricity, based on the forecast information.

Additionally, maintenance cycles may be planned based on forecastweather conditions. In situations where the availability of renewableenergy is substantially less than the expected energy, such as due toforecast information (e.g., rainy season, several days of low windcycles, shorten solar day, etc.), maintenance cycles may be planned inadvance, to minimize the loss of input energy.

Based on the received information, the control system determines andcommands, via signals, charging elements, power supply units, heaters,discharge blowers and pumps for effective and reliable energy storage,charging, and discharging. For example, the command may be given topower source controllers for solar energy, wind energy, and energy fromother sources. The control system 399 may also provide instructions tocontrollers which admit power to the entire heater array or to localgroupings of heaters.

The control system may include or be in communication with a forecastingand analytics system to monitor real-time and forecasting datacorresponding to one or more meteorological parameters associated withan area of interest (AOI) where the electrical energy sources are beinginstalled. The meteorological parameters can include, withoutlimitation, solar radiation, air temperature, wind speed, precipitation,or humidity. The control system, based on the monitored real-time andforecasting data of the meteorological parameters, may in someimplementations switch the electrical connection of the system betweenVRE sources and other energy sources. For instance, when the weatherforecast predicts that the availability of sunlight or wind will belower than a predefined limit for upcoming days, then the control systemmay command the system to electrically couple the heating elements ofthe system to other energy sources to meet the demands of a load systemfor the upcoming days.

In another example implementation, the control system monitors real-timeand forecast data regarding availability of VRE, and selects an energydischarge rate and command the system to operate at such rate, so as toallow the system to continuously produce energy during the forecastlower-input period. Continuous energy supply is beneficial to certainindustrial processes, making it is undesirable for a thermal storageunit to completely discharge itself and shut down.

It is also beneficial to certain industrial processes for adjustments inenergy supply to be made slowly, and to be made infrequently. Therefore,the control system in some implementations selects a new discharge ratebased on a multi-hour or multi-day weather forecast and correspondingVRE production forecast, so as to be able to operate at a fixed rate for(for example) a 24-hour period, or a 48-hour period, or a 72-hourperiod, given that forecast VRE supply. The control system mayadditionally and frequently update the information regarding a VREsupply forecast, and may make further adjustments to energy dischargerate so as to meet demand without interruptions, optionally providingsignals and interface mechanisms for operator input, adjustment oroverride as described above. Thus, the behavior of energy delivery iscontrolled based on the above explained parameters, includingforecasting.

In addition to forecasting of an input condition such as the weather,forecasting aspects of the thermal energy storage system may alsoinclude forecasting of energy markets and available sources and pricesof energy, along with supply and demand of the industrial applicationsat the output of the thermal energy storage system to tune the operationof system. The control system may use the forecast information tocontrol one or more aspects of the thermal energy system, includinginput of electrical energy, temperature of various elements of thethermal energy storage system, quantity and quality of the output heat,steam, or fluid (including gas), as well as improving the operation ofthe associated industrial processes. For example, the input electricitymay be received or purchased at a time when the cost of the electricityis lower, in conjunction with forecast information about the conditionsat the electricity source, and may be output when the demand or pricingof the output from the thermal energy storage system, or of powerproduced using that output, is higher.

Additionally, in situations where there is variability across differenttime periods as to the forecast conditions, the control system may makethe adjustments on a corresponding variable basis. For example, if theexpected cost of the input electricity is higher on a first day ascompared with a second day, the controller may control the variousinputs and outputs and parameters of the thermal energy system toaccount for differences in conditions between the first day and thesecond day that are based on differences in the initial forecast. Inaddition to the foregoing aspects, predictive analytics may be used tomore effectively plan for equipment maintenance and replacement cycles.For example, predictive analytics may be used in predicting whenmaintenance will be needed, based on historical data. These analyticsmay be used in conjunction with one or more of the above forecastaspects to provide for planned downtime, for example, to coincide withtimes when input power availability or pricing conditions make operationof the system less advantageous.

The foregoing controls may be provided to an operator that makesdecisions based on the forecasting information and the operation of thecontrol system. Alternatively, the control system may include someautomated routines that provide decision support or make determinationsand generate commands, based on the forecast information, in anautomated or semi-automated manner.

Charging/Discharging Modes

As explained above, the system can be operated in a charging mode forstoring electrical energy as thermal energy while simultaneouslygenerating and supplying steam and/or electrical power for variousindustrial applications as required. The charging and dischargingoperations are independent of one another, and may be executed at thesame time or at different times, with varying states of overlap asneeded, e.g. to respond to actual and forecast energy sourceavailability and to deliver output energy to varying load demands. Thesystem can also be operated in a discharging mode for supplying thestored thermal energy for steam and/or electrical power generation, aswell as other industrial applications. Optionally, the system may beused to provide heated gas to an industrial application directly withoutfirst producing steam or electricity.

A key innovation in the present disclosure is the charge-dischargeoperation of the unit in such a means as to prevent thermal runaway, byperiodically cooling each element of the storage media well below itsoperating temperature. In one implementation, this deep-cooling isachieved by operating the storage media through successive charge anddischarge cycles in which constant outlet temperature is maintained andeach storage element is deep-cooled in alternate discharge cycles. Thenarrative below refers process flow diagrams 1700 a-1700 h in FIGS. 19Athrough 21 for charge and discharge, according to the exampleimplementations.

At FIG. 19A, 1700 a, a flow diagram associated with a first chargingoperating pattern is shown. At 1701, power is flowing from an inputsource of electrical energy such as from a VRE source and operatingheaters within stacks 1725 and 1727. At 1703, an output of the storagearray is shown as steam.

As shown at valves 1705 and 1707, the controller 1751 provides a signalfor valve 1705 (a fluid flow control louver, damper, or other controldevice) to close for a first thermal storage array, and also provides asignal to a valve 1707 to be open for a second thermal storage array.Both units are heating, and flow through unit 1727 is providing flow todeliver heat to the steam generator.

With respect to the second unit 1727, the second unit is being charged,and flow is provided, as indicated by the valve 1707 being open. Thus,gas at the input temperature T_(low) flows by way of the blower 1721,via the dynamic insulation, through the valve 1707 and through thethermal storage of unit 1727 to the upper fluid conduit. The gas isheated by the stacks of bricks to an output temperature equal to orabove the desired fluid outlet temperature T_(high), which may be avalue such as 800° C.

A sensor 1742 may provide information to the controller 1751 about thetemperature of the gas prior to entering the steam generator. Thecontroller 1751 modulates the setting of valve 1741 to allow cooler airto mix with the air flowing through the stack of bricks to reduce theblended fluid temperature at point 1742 to the specified T_(high) value.The hot outlet air continues to flow, including through the steamgenerator 1709, which is supplied with water 1719 as controlled by pump1717, and cooled air at temperature T_(low) is forced by blower 1721through the dynamic insulation paths and back to the inlets of valves1705, 1707 and 1741. Additional sensors may be provided throughout thesystem, such as at 1713 and 1715. The controller 1751 may also use thesame communication and power lines to transmit commands to controlelements such as the valves 1705, 1707.

When charging stops, as for example occurs at the end of each solar dayor each windy period, discharging continues. In FIG. 19B, flow diagram1700 b depicts an example first process flow for the discharging modewithout concurrent charging. As shown herein, at the first unit 1725,the valve 1705 remains closed, based on the signal from the controller1751. Thus, there is lower or no gas flow to the first unit associatedwith the valve 1705. On the other hand, the valve 1707 is open withrespect to the second unit 1727, based on the signal from the controller1751. Thus, the gas continues to flow through the unit 1727, and thecontroller 1751 continues to modulate the setting of valve 1741 to causethe proper amount of cooler air to mix with the air flowing through thestack of bricks to maintain the fluid temperature at point 1742 to thespecified T_(high) value. The hot gas continues to be discharged to thesteam generator 1709, to generate the steam export 1703.

As each stack discharges, its outlet gas temperature remains roughlyconstant until approximately ⅔ of the usable heat has been delivered. Atthis point the outlet temperature from the stack will begin to drop, andcontinues dropping as discharge continues. The present innovation usesthis characteristic to accomplish “deep cooling” as operation continues.The controller 1751 senses a reduction in the temperature at point 1742and begins closing bypass valve 1741. By the time the outlet temperaturefrom unit 1727 has reached T_(high), valve 1741 reaches the fully closedposition, and as temperature further drops it is no longer possible forunit 1727 to deliver heat at temperature T_(high).

As shown at 1700 c in FIG. 19C, the discharge process is modified topartially open the valve 1705 based on the signal from the controller1751, so that the first unit 1725 begins discharging; its higher outlettemperature is now blended with air flowing through cooler stack 1727 tomaintain outlet temperature T_(high) at point 1742. The controller 1751now modulates valves 1707 and 1705 to vary the flow through stacks 1725and 1727 so as to maintain T_(high) at point 1742. At this point in thedischarge process, flow through stack 1727 emerges at temperature belowT_(high) and is blended with discharge from stack 1725 which is aboveT_(high) in proportions to ensure outlet at 1742 is maintained atT_(high). Thus, unit 1727 continues to be cooled by gas flow, and itsoutlet temperature continues to fall farther below T_(high), while thetemperature at 1742 is maintained at T_(high) by blending with thehigher-temperature air from stack 1725. As discharge of stack 1725proceeds, its outlet gas temperature begins to drop, and controller 1751begins to close valve 1707 in order to maintain temperature at 1742 atT_(high).

As shown in 1700 d in FIG. 19D, valves 1707 and 1741 are closed at thepoint that the outlet temperature of stack 1725 has reached T_(high).Note that at this point, the peak brick temperature in stack 1727 is farbelow the peak brick temperature in stack 1725—it has been “deep-cooled”below T_(high), by continuing to supply flow during the discharge ofstack 1727. The system would be fully “discharged”—unable to deliverfurther energy at temperature T_(high)—when the outlet temperature ofstack 1725 drops below T_(high).

In some implementations, it is beneficial for controller actions to havechosen a rate of discharge such that when next charging begins—as at thebeginning of the next solar day, for instance—the system is not yetfully discharged. 1700 e in FIG. 20A shows the next charging period, inwhich discharging remains constant. Charging energy is again supplied byVRE into both stacks. Stack 1727, which has been deeply cooled, ischarged without flow, and stack 1725 is being charged while providingflow to the system output. As the outlet temperature of stack 1725rises, controller 1751 again begins to open valve 1741 to maintain theblended system outlet temperature at T_(high).

At the end of this period of charging (electricity supply is again off),both stacks are fully charged, and discharging continues as in 1700 f asshown in FIG. 20B. Now stack 1725 is discharging while stack 1727 has noflow. As discharge proceeds and stack 1725's outlet temperature falls,controller 1751 first begins to close valve 1741, then begins to openvalve 1707 as shown in 1700 g in FIG. 20C. Discharging continues; asstack 1727's outlet temperature falls, controller 1751 progressivelycloses valve 1705, so that toward the end of the discharge cyclesubstantially all flow is coming through stack 1727 as shown in 1700 h,FIG. 21 . As the next charging cycle begins, the system is now in thestate shown in 1700 a in FIG. 19A.

Thus it will be understood that through actions of the controllerresponding to the measured and/or modeled state of charge of each stack,in successive charge/discharge cycles each stack is cooled to a gasoutlet temperature of approximately T_(high) in a first cycle and a gasoutlet temperature substantially below T_(high) in a second cycle. Thisalternating deep-cool operation effectively prevents thermal runaway.Those skilled in the art will recognize that this technique may beapplied in larger systems with more than two independent stacks, forinstance by organizing the system into pairs which operate as shown herein parallel or in series with other pairs; or by arranging more than twostacks in a deep-cool operating pattern.

Flow through the one or both of the stacks may be varied, as explainedabove. To avoid overheating and to control the output temperature, allor a portion of gas may be diverted by one or more baffles or flowcontrol devices to a bypass 1741, controlled by the controller 1751,such that the inlet gas is mixed with the discharge gas of the stacks,to provide the output at a constant temperature or specified,non-constant temperature profile.

FIG. 22 also illustrates the charging and discharging modes of a system1800, which includes thermal storage structure 1801 having first section1803 and second section 1805. As has been described, system 1800 can beelectrically connected to an electrical energy source, and canfacilitate supplying this electrical energy to heating elements 1813associated with at least some portion of thermal storage 1807 withinfirst section 1803 during a charging mode. Heating elements 1813 mayreceive electrical energy at a controlled rate and emit thermal energysuch that the bricks can absorb the emitted thermal energy andcorrespondingly become heated to some desired temperature. As a result,thermal storage 1807 can store the received electrical energy in theform of thermal energy.

As shown, system 1800 may also be required to simultaneously generatesome combination of hot gas, supply steam and/or other heated fluid forvarious industrial applications. This output may be facilitated withinsecond section 1805 within thermal storage structure 1801, whichincludes a pump 1821 that provides water to a first end 1817 of aconduit 1815. Accordingly, during a discharging mode, blower units 1823can be actuated to facilitate the flow of a gas such as air from one endto the other of thermal storage 1807 (e.g., from the bottom to the top),and from there into second section 1805 such that the gas passingthrough the first section can be heated to absorb and transfer thethermal energy emitted by the heating elements 1813 and/or thermalstorage. This flow of heated air passes into second section 1805, whichallows conduit 1815 to convert the water flowing through the conduit1815 into steam and facilitate outflow of the generated steam through asecond end 1819 of conduit 1815.

Alternatively, during simultaneous charging and discharging, gas flowthrough thermal storage 1807 may be minimal or none, and all or aportion of gas from blowers 1823 may be diverted by one or more bafflesor flow control devices, and may be heated by a separate bypass heater(not shown) to deliver inlet gas, such as inlet air, to the steamgenerator at a suitable temperature. This bypass mode of operation maybe beneficial in achieving predefined temperature distributions inthermal storage and in mitigating the required power dissipation of theheating elements.

In some configurations, the only required output from the thermalstorage structure is the output of hot gas (e.g., hot air) to anindustrial process. Accordingly, a steam generator may either not bepresent or not used. In such configurations, a separate conduitconnecting to a processing chamber may be provided to facilitatedelivery of the hot gas.

In another implementation, if the available electrical energy beingreceived by the structure 1800 is low, then during charging mode, asmaller number of the total number of available heating elements 1813receive the limited available electrical energy. Accordingly, only aportion of thermal storage is heated during charging mode. Duringdischarging, gas can be passed largely through only the portion ofthermal storage 1807 that has been heated. The heated gas thus continuesto transfer the stored thermal energy to the conduit 1815 in order tokeep the temperature of the gas at the conduit 1815 sufficiently high tomaintain continuous and controlled steam production, thereby preventingany damages or failure in the steam production system.

Simultaneous Charge-Discharge Alternate Heater

Implementations discussed above have described the flow of a fluid suchas air into a first section of a thermal storage structure that includesthe thermal storage material itself, and from there into a secondsection of the thermal storage structure that includes an output devicesuch as a steam generator.

Other fluid flows within the thermal storage structure are alsocontemplated. In some implementations, the system is configured to causea heated air flow to be directed into the second section, without firsthaving flowed through the first section. In such implementations, thesystem is configured to heat inlet air using a heater that iselectrically connected to the electrical energy sources. In this manner,the air may be heated to a same temperature range that would be expectedfrom heated air being output from the thermal storage. This mode may beutilized in charging mode, during which time the energy supply from theelectrical energy source is likely to be plentiful, and therefore lesscostly. A heater powered by the input electrical energy receives inletair (e.g., which may be ambient air, recirculated air, etc. that iscooler than the peak temperatures of air produced by the thermalstorage), heats the inlet air, and directs it to the second section ofthe thermal storage structure, where it may pass over a conduit of anOTSG, for example. During this operation, the system may allow verylittle or no air to pass through the thermal storage such that chargingis performed efficiently without discharging into the second sectionbefore discharging mode is initiated.

In another type of air flow, the thermal storage structure can beconfigured to facilitate the passive outflow of heated air from thehousing due to the buoyancy effect of heated air. This may be used toprovide intrinsic safety for people working in areas near the unit andfor the equipment itself, without requiring active equipment or standbyelectric power sources to maintain safe conditions. For example, if pumpor blower motors or drives fail, if control systems fail, or if theoperating electric power supply fails, the present innovations includefeatures that cause air to flow in such a manner as to provide ongoingcool temperatures at exterior walls, foundation, and connected equipmentpoints. This type of operation can maintain the temperature of all partsof the system within safety limits and prevent any potential harm topeople, the environment, other equipment or the components of the systemfrom being thermally damaged.

FIG. 18 is a block diagram of a system 1600 that illustrates these airflows. As shown, thermal storage structure 1601 includes a first section1603 that includes thermal storage blocks 1607, a second section 1605that includes a steam generator 1615, and a thermal barrier 1625separating the two sections. Further, as described above, insulation isprovided with an air gap that allows for the dynamic insulation ofthermal storage 1607.

A blower 1621 takes inlet air from louver 1619 and directs it to thermalstorage blocks 1607. Air that has passed through the thermal storageblocks 1607 can then pass into second section 1605 during a dischargingmode. As an example of another air flow, release valve 1623 may becontrolled to allow for the release of hot air, and inlet valve 1619 maybe opened to allow for the intake of ambient air, such as in the eventof a need for quick shutdown or emergency. By suitable arrangement ofthe valve locations and air flow paths, a “chimney effect” orbuoyancy-driven air flow may establish suitable air flow through thedynamic insulation and system inlets to maintain cool outer temperaturesand isolate the steam generator or other high-temperature process fromthe storage core temperatures, without active equipment.

Auxiliary heater 1609 is a type of auxiliary heater that can be used toheat a portion of the fluid (such as air) moving through the thermalstorage structure. As shown in FIG. 18 , auxiliary heater is positionedin the thermal storage structure, but may also be located outside of thethermal storage array. In the case of the auxiliary heater 1609 beingpositioned in the thermal storage structure, the portion of the fluidmay pass through the bypass described below with respect to FIGS.19A-19D, 20A-20C and 21-33 . Another type of auxiliary heater that maybe used in some implementations is a heater positioned between the fluidoutput of a thermal storage medium and an inlet of a load system thatthe fluid is delivered to. Such a heater may be used in some embodimentsto increase an output temperature of the fluid provided by a thermalstorage structure.

These are just two examples of multiple possible fluid flows withinsystem 1600. As has been described, system 1600 is configured to receiveinlet fluid at inlet valve 1619. This fluid may variously be directeddirectly to the dynamic insulation or directly to thermal storage 1607.Optionally, the system can include one or more louvers 1611 positionedat the bottom of the stacks within first section 1603, and areconfigured such that the flow path of the fluid flowing through each ofthe storage arrays and thermal storage elements is as uniform aspossible such that constant air pressure is maintained across eachthermal element for efficient charging and discharging. Still further,inlet fluid may be directed to second section 1605 via auxiliary heater1609, as controlled by a louver 1611 positioned between the blower 1621and the auxiliary heater 1609, without passing through the dynamicinsulation or thermal storage 1607.

Additionally, fluid flow from the top of the stacks within thermalstorage 1607 may be provided to steam generator 1615 via a valve 1613between first section 1603 and second section 1605. Valve 1613 canseparate receive fluid flows produced from each of the stacks in thermalstorage 1607. For example, in the case in which two stacks are used,valve 1613 can receive a first fluid flow from a first stack and asecond fluid flow from a second stack. Valve 1613 can also receive abypass fluid flow, which corresponds to fluid (such as from louver 1619)that has not passed through either the first or second stacks. As willbe described below in the context of the lead-lag paradigm, valve 1613is controllable by the control system to variously output no fluid, acombination of the first fluid flow and the bypass fluid flow, acombination of the second fluid flow and the bypass fluid flow, acombination of the first and second fluid flows, etc. In order toachieve an output fluid having a specified temperature profile. Louver1619 can also be used to release cool fluid from the system instead ofrecirculating it to thermal storage 1607, in the event that the bloweris not operational, for example.

While the foregoing example includes the bypass heater louvers, such ashigh-temperature louvers, these features are optional. Further, thebypass heater may have an advantage, in that it can reduce the requiredheater power within the array. In other words, the bypass heater maydischarge heat during charging, without passing air through the arrayduring charging.

Note that various other control valves are contemplated, including thosedescribed below with reference to FIGS. 35(A)-(B).

These air flows and associated control structures may provide benefitsin terms of safety and temperature regulation, in addition to thebenefit of efficient charging and discharging.

The selection of charging and discharging modes may be made by a controlsystem on an automatic schedule based on, for example, measurements oftemperature or power distribution. Similarly, other features such as thehot air booster mode described above may also be controlled by thecontrol system based on conditions detected within the thermal storagestructure.

Such sensing may include measurements of radiation by cameras,spectrometers, or other devices, and may include remote measurementscarried by optical waveguide systems including fiber optic, fixedreflector, and movable reflector systems; measurements of temperaturebased on measurements of resistance or current flow in heating elements;direct sensing of temperatures within the refractory array, within flowchannels exiting the array, or by other sensing means or locations.

Next, the use of a particular type of discharging—“deep discharging”—isdescribed.

Lead-Lag and Avoiding Thermal Runaway

Thermal energy storage systems are vulnerable to “thermal runaway” or“heat runaway” effects. The phenomenon may arise from imbalances inlocal heating by heating elements and imbalances in local cooling byheat transfer gas flow. Even small imbalances may be problematic, whichare amplified across successive charge-discharge cycles. After severalcycles, even small imbalances may result in large temperaturedifferences which may be damaging to bricks and/or heaters, and/orseverely limit the temperature range within which the system can besafely operated.

FIG. 23 provides an example 2000 illustrating how heating imbalanceswithin heating storage arrays may lead to thermal runaway. For each ofmultiple points in time, example 2000 depicts temperatures associatedwith fluid flow conduits 2010 and 2020, each of which passes through adifferent thermal storage array. (For ease of reference, the arraysthrough which conduits 2010 and 2020 pass may be referred to as arrays 1and 2, respectively). As shown, different portions or layers of theconduits are heated by different heating elements, indicated as heatingelement pairs 2031A-2036A and 2031B-2036B.

Point in time 2050 corresponds to an initial, fully charged state forboth arrays 1 and 2. In this state, the conduits are heated to 1000° C.along each section of their lengths. In the case of solar energy input,such a state might to correspond to arrays at the end of a solar day.While the value of 1000° C. is included, this is just an example, andthe temperature may be varied depending on factors such as applicationsor use points. For example, the conduits may be heated within a range of800° C. to 1600° C., and more specifically, 900° C. to 1300° C., andeven more specifically, 800° C. to 1100° C. Other factors that mayimpact the temperature include temperature impact on heater life,storage capacity, heating patterns, weather conditions, temperature, andheater materials. For example, a ceramic heater may have an upperconduit temperature range as high as 1500° C. to 1600° C., whereas otherheaters may have a conduit temperature range of 600° C. to 700° C. Therange of conduit temperatures may be varied vertically within the stackby varying the brick materials.

At the beginning of discharge period 2051 (e.g., dusk in the case ofsolar energy input) of the arrays, cooler heat transfer gas isintroduced at the bottom of the arrays and flows upwards. During thecharging period that has just concluded, heat has been added by heatingelements 2031-2036, which may be oriented transverse to the fluidcolumns and grouped by horizontal position within the array. Ideally,the same input energy will have been supplied to all heating elements ineach group, but in practice, individual heating units vary slightly intheir resistance (and thus their power delivery). Similarly, localcooling flow rates will vary between conduits, given that individualchannels vary in roughness, brick alignment, or are otherwise mismatchedin their resistance to flow.

Here, example 2000 assumes that the flow rate in conduit 2020 is belowthe flow rate in 2010. Accordingly, portions of array 2 adjacent toconduit 2020 will exhibit higher temperatures than portions of array 1adjacent to conduit 2020, due to the lower cooling flow. The result atthe end of discharge period 2051 is shown in FIG. 23 . Arrays 1 and 2both exhibit a “thermocline” temperature distribution, as the bricks atthe lower layers of arrays 1 and 2 are cooler than those at the upperlayers. This phenomenon results from the discharge period being stoppedwhen a particular outlet temperature (i.e., a temperature at the top ofthe array)—600° C. in the case of array 1. Furthermore, due to the lowercooling flow in array 2, material temperatures around conduit 2020 inarray 2 are roughly 300° C. higher than those around correspondinglayers of conduit 2010 in array 1. For example, the top layer of array 1is at 600° C., while the top layer of array 2 is at 900° C.

These variations in heating and cooling rates, unless managed andmitigated, can lead to runaway of mismatched storage elementtemperatures, and can lead to runaway temperatures that cause failuresof heaters and/or deterioration of refractory materials within thearray.

At the end of discharge period 2051, the control system determines howmuch energy to apply to each heating element group during a charging (orrecharging) period in order to restore the full state of charge. But thecontrol system may not have information about every temperaturenonuniformity within every location within a set of thermal storagearrays. For example, there might be a limited number of sensorsavailable, and thus temperature nonuniformities may be undetected.Sensors may also malfunction. In some implementations, the heatingelements may be controlled by a model-based paradigm in which sensorsare not used or are used in a limited fashion. The system may also notbe configured to vary heating to a fine enough granularity to resolveevery area of temperature nonuniformity. In example 2000, it isdetermined that heating elements 2031 are given enough total energy toraise the surrounding materials by 800° C., while heaters 2036 are givenenough energy to raise their surrounding materials by 400° C.

At the end of a charging period 2052 that uses the above-noted heatingparameters, the temperature differences at the end of discharge period2051 remain. This is due to inefficient discharging of conduit 2020relative to conduit 2010, and conduit 2020's higher residual temperatureat the end of discharge period 2051. Accordingly, the amount of inputenergy received during charging period 2052 overheats conduit 2020 alongits length by roughly 300 degrees. Note that over the course of a singledischarge and charge cycle, temperatures along conduit 2020 are now250-300° C. warmer as compared to fully charged state 250. If anothercycle were repeated (that is, another discharge period followed byanother charge period), the overheating of conduit 2020 would be evenmore pronounced. (The values shown in FIG. 23 are for example purposes;realistic temperature mismatches might grow more slowly, but could reacha critical level over repeated cycles.) This increase in temperatureover time due to local temperature nonuniformities is thermal runaway,and can cause early failure of heating elements and shortened systemlife.

An effect that exacerbates this runaway is the thermal expansion offluid flowing in the conduits. Hotter gas expands more, causing a higheroutlet velocity for a given inlet flow, and thus a higher hydraulicpressure drop across the column. This effect may contribute to a furtherreduction of flow.

The present disclosure teaches several techniques that may be used tomitigate thermal runaway in a manner that achieves long-term, stableoperation of the thermal energy storage system.

First, the height of the storage material stack and the physicalmeasurements of the fluid flow conduits may be chosen in such a mannerthat the system is “passively balanced.” Low fluid flow rates areselected for system discharge, and flow rates and conduit geometries aredesigned with a relatively low associated hydraulic pressure drop andlong column length. In this configuration, the lower density of hottergas will create a “stack effect,” a relative buoyancy component to theflow rate, which increases fluid flow in hotter conduits. Thismismatched cooling flow provides a balancing force to stabilize andlimit temperature differences across the thermal storage array.

Second, a “deep-cool” sequencing is used to rebalance or leveltemperature differences among conduits. This concept can also bereferred to as a deep discharge (also referred to as “deep-discharge”).Generally speaking, deep discharging refers to continuing discharge ofone or more arrays until temperature nonuniformities within the arrayhave reduced (such arrays can thus be said to have been “deeplydischarged,” which amounts to a thermal reset). The amount of dischargeof an array might be measured in several ways, such as by a comparisonof the array's total bulk temperature to that of the inlet gastemperature from inlet or bypass air admitted through an inlet valve. Adeep discharge of an array may be contrasted with a partial discharge ofthe array, in that during a deep discharge, gas flows through the arrayfor a longer period of time (and potentially with greater flow volume)than during a partial discharge. In some applications of a deepdischarge, an array may be fully discharged to the inlet airtemperature, which may also be referred to as bypass temperature. Theoperations sequence shown in FIGS. 19A-21 disclose one “deep discharge”method of operation.

Consider the effect of deep-discharge period 2054. By discharging arrays1 and 2 more completely than in discharge period 2051 (e.g., by flowinggas over the arrays for a longer period of time), it can be seen thatarrays 1 and 2 discharge more uniformly during deep-discharge period2054. Temperatures in array 1 range between 300-310° C., whiletemperatures in array 2 range between 310-480° C. Accordingly,subsequent charging period 2055 results in a temperature distributionwithin both arrays 1 and 2 that more closely approximates starting point2050, and thus greatly reduces thermal runaway within the thermalstorage.

Deep discharging is thus an effective solution to the problem of thermalrunaway within a thermal storage array. But thermal runaway is not theonly constraint on the thermal energy storage systems contemplated inthis disclosure. As noted, it is desirable for thermal energy storagesystems to be able to provide a continuous or near-continuous supply ofthermal energy for downstream processes. This requires that at leastsome media within the storage unit be at temperatures above the requireddelivery temperature. The present inventors have realized that whiledeep-discharge is desirable for thermal storage arrays, discharging allarrays in a system every discharge cycle is not possible, as it wouldcreate periods when no element within the system has sufficienttemperature to meet outlet temperature requirements. Accordingly, theinventors have developed a paradigm of only periodicallydeep-discharging each thermal storage array in a set of one or morestorage arrays. This approach meets the dual objectives of periodicallyperforming a thermal reset of each thermal storage array and maintainingsufficient temperature within the thermal storage to meet outlettemperature specifications.

One specific implementation that is contemplated includes the use of twothermal storage arrays, and is referred to as the “lead-lag” technique.In this technique, the system deep-discharges each of the two thermalstorage arrays every other discharge period. For example, array 1 wouldbe discharged in discharge periods 0, 2, 4, etc. and array 2 would bedischarged in discharge periods 1, 3, 5, etc.

The process elements for a lead-lag operation are shown in FIGS. 19Athrough 21 , and the conceptual lead-lag temperature profiles are shownin FIGS. 24 and 25 , which illustrate the discharge temperature of afirst stack and a second stack in a thermal energy storage system, aswell as a temperature of a blended fluid flow that is provided as anoutput.

FIG. 24A illustrates an example configuration 24000 associated with theconcept of lead-lag. More specifically, a first stack 24001 and a secondstack 24003 are provided that are each configured to receive inletfluid, as well as a bypass 24005, which is also configured to receiveinlet fluid. Respective valves 24007, 24009, and 24011 control airflowinto the first stack 24001, the second stack 24003 and the bypass 24005,based on inputs received from the controller, as explained above withrespect to FIGS. 19-21 . The control of the flow will be explained belowwith respect to FIGS. 24-33 .

As shown in chart 2060Aa, temperature is shown along the vertical axis,while time is shown along the horizontal axis. A peak temperature 2061of the first stack and the second stack are shown, along with bypasstemperature 2063, which is the inlet gas temperature. Additionally, at2065, a delivery temperature of the stream of blended output fluid flowis shown. The horizontal axis shows time, including 24-hour intervals2067 and 2067 a, as well as a solar day at 2069 and 2069 a.

The peak temperature of the first stack is indicated by line 2071, whilethe peak temperature of the second stack is indicated by line 2073. Aswill be shown, the first stack and the second stack operate togethersuch that the first stack is in a “lead” mode of operation when thesecond stack is in a “lag” mode of operation, and vice versa. During thefirst day, the first stack is cooled to a very low temperature relativeto both peak temperature 2061 and delivery temperature 2065, while thesecond stack is cooled to a minimum required temperature to deliver theoutput at the delivery temperature 2065, which is shown here as aconstant. On the second day, the second stack is cooled to the lowertemperature while the first stack is cooled to the delivery temperature.

In short, in the case where two stacks are operating together, eachstack may be deeply discharged to well below the delivery temperatureevery other discharge period. Similarly, in those discharge periods inwhich a given stack is not being deeply discharged, it is dischargedfrom the peak discharge temperature to the delivery temperature (or atemperature approaching the delivery temperature). The cycling betweenthe lead mode and the lag mode for a given stack is accomplished by thecontrol system controlling the flow of fluid in each of the stacks. (Inthe lead mode, a given stack is deeply discharged, while in the leadmode, the given stack is discharged to a temperature at or above thedelivery temperature.) The stack that is being deeply discharged maycontinue to be heated by having the resistive heating elements receivethe electrical energy and emit heat; alternatively, the resistiveheating elements may be switched to an off state.

At the leftmost position of the chart 2060Aa, the first stack and thesecond stack are both at the peak temperature 2061. This startingposition may occur outside the solar day such as at midnight. Then, asindicated by line 2071, the first stack begins discharging. As thetemperature of the first stack starts to fall and continues to fall tobelow the output delivery temperature, hot fluid from the second stackis blended as shown at 2073. As the temperature of the first stackcontinues to fall, the flow through the first stack is reduced andadditional heated fluid is blended in from the second stack, in order tomaintain delivery temperature 2065.

The first stack continues to discharge until it reaches or approaches aminimum temperature, which, in this example, corresponds to bypasstemperature 2063 and represents a fully discharged state of the firststack. This minimum temperature is, in some cases such as in chart2060A, a temperature that approximates the bypass temperature. Thedegree to which the minimum temperature approximates the bypass/inletgas temperature may depend on factors such as the quality of heattransfer out of the bricks, as well as a difference between deliverytemperature 2065 and peak temperature 2061. For example, if peaktemperature 2061 were 1000° C. and delivery temperature 2065 were 900°Celsius, the amount of cool air that can be blended into the air that is1000° C. is relatively small. Thus, minimum temperature 2063 to whichthe stack can be cooled may be higher, such as 800° C. On the otherhand, if the delivery temperature 2065 were lower, such as 650° C., thenthe minimum temperature 2063 to which the stack can be deeply cooled maybe lower, such as around 200° C. Thus, the lower delivery temperature2065 is relative to peak temperature 2061, the lower minimum temperature2077 can be set relative to bypass temperature 2063. Thus it is notnecessarily the case that a stack must be discharged to the bypasstemperature in order to achieve deep discharging. Rather, dischargingmay occur within a range of temperatures (a “deep-discharge temperatureregion”) that is sufficient to reduce thermal runaway by reducingthermal nonuniformities. In some cases, the range of a deep-dischargetemperature region for a particular use case is bounded on the upper endby the delivery temperature and on the lower end by the inlet gastemperature, the bounds including both the delivery temperature andinlet gas temperature (or bypass temperature) in the region. As noted,the bounds for this region for a particular situation will vary, forexample based on the peak temperature and delivery temperature, and maybe more specifically determined in some cases by monitoring the thermalbehavior of the thermal storage arrays. Alternately, a deep-dischargetemperature region may be determined via execution of a computermodeling program.

During the deep discharging of the first stack, the bypass valve may beturned off, such as by starting to close the louver on the bottom of thestacks as controlled by the control system, to accelerate the coolingprocess. At this point, the second stack is being used as the primarysource of heated fluid to provide the blended stream at deliverytemperature 2065. Further, as explained above, fluid may be flowedthrough the fluid bypass valve so that the fluid is provided at theinlet temperature to the blended stream. The fluid bypass may be used tobypass fluid directly to the blended fluid flow, in order to bring thetemperature down at a time when both of the stacks become too hot, suchas towards the end of the solar day.

As the second stack continues to discharge, its discharge temperaturestarts to approach the delivery temperature 2065, as shown at 2081. Thedischarge may be buffered, such that the minimum discharge temperatureof the second stack is higher than the constant delivery temperature2065, as shown at 2081 z. This temperature of the second stack is theminimum temperature at which the blended stream can be provided atdelivery temperature 2065. Here, the temperature of the first stack at2079 is substantially cooler than the temperature of the second stack at2081.

At this point, which is at or around the start of the solar day (e.g.,dawn), the flow to the first stack is turned off at 2079, and the firststack begins to charge as shown by a broken line 2083 in FIG. 24 . Atthis point, the heaters are on for both the first stack and the secondstack. Because there is no fluid flow through the first stack, however,the slope of the line indicating heating is greater than that of thesecond stack, in which fluid flow is occurring.

Alternatively, as shown in 25, fluid continues to be trickled throughthe first stack as it increases its discharge temperature. The tricklemay account for the possibility that the units are not sealed in such amanner that would permit 0% flow, and that the louvers permit a residualflow, such as 5% or the like. Further details of this approach areexplained with respect to FIG. 28 .

Returning to FIG. 24 , after a period of charging, both the first stackand the second stack become fully charged by 2085, which, in thisexample, occurs during the solar day. In this example, the second stackcontinues to provide the hot fluid output at the peak temperature whilethe first stack continues to charge between 2085 and 2087. On the otherhand, louvers of the first stack are fully closed at this point, suchthat there is essentially no fluid flow through the first stack.

At 2087, the roles of the first stack and the second stack are reversed,such that the second stack begins to discharge to a deeply dischargedstate while the first stack continues to provide the fluid for theblended stream, so as to maintain constant delivery temperature 2065.The remainder of the timeline shown in FIG. 24 is similar to thatdescribed for the first 24-hour interval.

At the end of the first 24-hour period cycle 2067 and the start of thesecond 24-hour period cycle 2067 a (i.e., at 2087), the second stack andthe first stack are both at peak temperature 2061. As can be seen at2071 a, the second stack begins discharging. As the temperature of thesecond stack starts to fall and continues to fall to below the deliverytemperature, hot fluid from the first stack is blended at 2073 a. As thetemperature of the second stack continues to fall, the flow through thesecond stack is reduced and additional heated fluid is blended in fromthe first stack to maintain delivery temperature 2065.

The second stack continues to discharge, such as until it reaches aminimum temperature at 2077 a or other discharge temperature.

During the deep discharging of the second stack, the bypass valve may beturned off, such as by starting to close the louvre on the bottom of thestacks as controlled by the control system, to accelerate the coolingprocess. At this point, the first stack is being used as the primarysource of heated gas to provide the blended stream at deliverytemperature 2065.

As the first stack continues to discharge, its discharge temperaturestarts to approach delivery temperature 2065, as shown at 2081 a. Thedischarge may be buffered, such that the minimum discharge temperatureof the second stack is higher than the constant delivery temperature2065, as shown at 2081 za. This temperature of the first stack is theminimum temperature (or approximately the minimum temperature) at whichthe blended stream can be provided at delivery temperature 2065. Here,the temperature of the second stack at 2079 a is substantially coolerthan the temperature of the first stack at 2081 a.

At 2079 a, which is at or around the start of the solar day, the flow tothe second stack is turned off, and the second stack charges as shown bybroken line 2083 a of FIG. 24 . At this point, the heaters are on forboth of the second stack and the first stack.

Alternatively, as shown in FIG. 25 , fluid continues to be trickledthrough the second stack as it increases its discharge temperature. Thetrickle may account for the possibility that the units are not sealed insuch a manner that would permit 0% flow, and that the louvers permit aresidual flow, such as 5% or the like. Further details of this approachare explained with respect to FIG. 28 .

The first stack continues to provide the hot fluid at the peak dischargetemperature while the second stack continues to charge between 2085 aand 2087 a. On the other hand, louvers of the second stack are fullyclosed at this point, such that there is essentially no fluid flowthrough the second stack.

This pattern of having a lead stack and a lag stack repeats (e.g., every48 hours). Accordingly, the first discharge operation in dischargeperiod of 2067 d 1 and the second discharge operation in successivedischarge period 2067 d 2 can be repeated, such that the control systemalternates between performing the first discharge operation(deep-discharging the first stack but not the second stack) and thesecond discharge operation (deep-discharging the second stack but notthe first stack) over time, allowing the system to continuously providean output fluid flow, and to do so while avoiding thermal runaway. Thisapproach need not be limited to a first stack and a second stack, andmay be used with more than two stacks (e.g., triples, quads, or thelike) as will be described further below.

FIG. 26 provides a detailed illustration of the temperature and gas flowaccording to the lead-lag implementation. The common features with FIG.24 are indicated with common reference numerals in chart 2060B,including a peak temperature 2061 b, a bypass temperature 2063 b and adelivery temperature 2065 b. Further, a 24-hour period 2067 b and asolar day 2069 b are shown along the horizontal axis. Air flow is alsoindicated along the right side of FIG. 26 . While the descriptionaccompanying FIG. 26 refers to hot air flow, it can also be generalizedto refer to fluid flow.

At the left side of chart 2060B, the beginning of the timing shown isassociated with an end of the solar day. At this point the first stackand the second stack are both at the peak temperature, in this case1000° C. At 2071 b, the first stack is discharging hot air at 1000° C.,while the second stack is not discharging hot air as indicated at 2070b, with an air flow of 0%. As explained above, the discharge temperaturemay vary between 800° C. to 1600° C., depending on various factors. Thetemperature of the bricks approaches the temperature of the conduit,usually within 25° C. to 50° C. For example, the conduits may be heatedwithin a range of 800° C. to 1600° C., and more specifically, 900° C. to1300° C., and even more specifically, 800° C. to 1100° C. Other factorsthat may impact the temperature include temperature impact on heaterlife, storage capacity, heating patterns, weather conditions,temperature, and heater materials. For example, a ceramic heater mayhave an upper conduit temperature range as high as 1500° C. to 1600° C.,whereas other heaters may have a conduit temperature range of 600° C. to700° C. The range of conduit temperatures may be varied verticallywithin the stack by varying the brick materials. Both of the stackscontain very hot air at the end of the solar day; the bypass unit isflowing in air at the inlet air temperature as the deep-dischargetemperature 2063 b.

As the flow of the first stack increases from about 60% to 100%, e.g.,60% to 100%, of the total airflow as indicated by 2072 b, the dischargetemperature of the first stack starts to decrease at 2073 b. As thedischarge temperature of the first stack starts to decrease, the bypassflow is also decreased downward from about 40%, e.g., 40%, of the totalair flow.

When the discharge temperature at the first stack falls below deliverytemperature 2065 b, as depicted at 2075 b, the flow of the first stackis now 100% of the total airflow as indicated by 2077 b, and the flow ofthe bypass and the second stack are both 0%, as indicated by 2076 b. Atthis point, in order to maintain the delivery temperature of the blendedair at 2065 b, air flow is turned on to the second stack at 2076 b.

As the air flow at the second stack increases and the air flow at thefirst stack decreases, the first stack continues to cool, but the rateof cooling slows as the flow through the second stack is reduced, asshown at 2078 b. Conversely, as the air flow at the second stackincreases, the second stack begins to cool, and as the air flow of thesecond stack approaches 100% of the total air flow at 2074 b, thedischarge temperature at the second stack starts to rapidly decreaseuntil it reaches the constant delivery temperature as shown in 2079 b.At this point, the air flow of the first stack is 0% as shown at 2080 b.

Once the discharge temperature of the second stack reaches the minimumtemperature at which the constant delivery temperature 2065B can bemaintained (as indicated by 2079 b), the airflow through the secondstack is decreased, and the discharge temperature of the second stackcorrespondingly rises at 2082 b. At the same time, because this isoccurring during the late solar day, the bypass flow is used to preventoverheating at 2076 b′. Further, because there is no flow through thefirst stack, the discharge temperature of the first stack increasesrapidly as the first stack charges, as indicated by 2081 b. At 2083 b,the first stack and the second stack have discharge temperatures equalto or approaching peak temperature 2061 b.

At 2083 b, the 24-hour cycle is now complete. The first and secondstacks now switch roles, such that the second stack will “lead” andundergo deep cooling, and the first stack will “lag” and act as thesecond stack did in the first 24-hour cycle. The bypass will continue tooperate in a similar manner. A second 24-hour period 2067 ba and a solarday 2069 ba are indicated along the horizontal axis.

At the end of the first 24-hour period cycle 2067 b and the start of thesecond 24-hour period cycle 2067 ba (i.e., at 2087 ba), the timing isassociated with an end of the solar day. At this point the second stackand the first stack are at the peak temperature, in this case 1000° C.As shown at 2071 ba, the second stack is discharging hot air at 1000°C., while the first stack is not discharging hot air as indicated at2070 ba, with an air flow of 0%. As before, the bypass unit is flowingin air at the inlet air temperature (deep-discharge temperature 2063 b).

As the flow of the second stack increases from about 60% to 100%, or 60%to 100%, of the total airflow as indicated by 2072 ba, the dischargetemperature of the second stack starts to decrease at 2073 ba. As thedischarge temperature of the second stack starts to decrease, the bypassflow is also decreased downward from about 40%, or 40%, of the total airflow.

When the discharge temperature at the second stack falls below theconstant delivery temperature 2065 b, as depicted at 2075 ba, the flowof the second stack is 100% of the total airflow as depicted at 2077 ba,and the flow of the bypass and the first stack are both 0%, as depictedby 2076 ba. At this point, in order to maintain the constant deliverytemperature of the blended air at 2065 b, air flow is turned on to thefirst stack at 2076 ba.

As the air flow at the first stack increases and the air flow at thesecond stack decreases, the second stack continues to cool, but the rateof cooling slows as the flow through the first stack is reduced, asshown at 2078 ba. Conversely, as the air flow at the first stackincreases, the first stack begins to cool, and as the airflow of thefirst stack approaches 100% of the total airflow at 2074 ba, thedischarge temperature at the first stack starts to rapidly decreaseuntil it reaches the constant delivery temperature as shown in 2079 ba.At this point, the air flow of the second stack is 0% as shown at 2080ba.

Once the discharge temperature of the first stack reaches the minimumtemperature at which delivery temperature 2065 b can be maintained(i.e., at 2079 ba), the air flow through the first stack is decreased,and the discharge temperature of the first stack correspondingly risesat 2082 ba. At the same time, because this is occurring during the latesolar day, the bypass flow is used to prevent overheating at 2076 ba.Further, because there is no flow through the second stack, thedischarge temperature of the second stack increases rapidly as thesecond stack charges, as indicated by 2081 ba. At 2083 ba, the secondstack and the first stack have discharge temperatures equal to orapproaching peak temperature 2061 b.

Structures such as valves, blowers, louvers and other mechanisms neededto accomplish the above-described operations are operated in response tocommands received from the control system. The control system isconfigured to generate the instructions based on a variety ofinformation, including a combination of sensed information, forecastinformation, and historical information, as well as models developedbased on, for example, artificial intelligence. For example, sensors maybe provided to ensure that the system is safe, in combination with aphysical model of how the system performs with different inputs inenergy—this model may thus serve as a substitute for some sensors invarious embodiments. In some cases, sensors may be expensive and maywear out or need replacement, and could cause additional problems. Forexample, a defective sensor may lead to system overheating. The modelmay take temperature inputs, and may allow for predictions based onparameters such as sunrise and weather. The model may be adjusted basedon the industrial application for a variety of reasons, such as tooptimize output temperature, energy output, or a combination thereof.

As has been described with reference to 2060B, the control system isconfigured to direct fluid flows (e.g., a first flow associated with thefirst stack, a second flow associated with the second stack, and abypass flow that bypasses the first and second stacks) in order todeeply discharge the first stack but not the second stack during firstdischarge period 2069 bd 1 and to deeply discharge the second stack butnot first stack during second discharge period 2069 bd 2. The operationsof the first and second discharge periods may be performed repeatedly insuccessive discharge periods, alternating between the operations of 2069bd 1 and 2069 bd 2. In the first discharge period, the second stack isdischarged to a lesser degree than the first stack—to the current valueof the specified temperature profile. Similarly, in the second dischargeperiod, the first stack is also discharged to a lesser degree than thesecond stack—to the current value of the specified temperature profile.The specified temperature profile 2065 b shown in FIG. 26 is a constanttemperature profile, but such temperature profiles may vary, as will bedescribed with respect to FIG. 29 .

It is understood that these temperature and flow illustrations are justexamples, and the actual values and shapes of curves may vary. As onesimple example, the peak temperature may be reduced during summer. Someexamples of variations are provided as follows.

FIG. 27 provides a detailed illustration 2060C of a temperature andfluid flow according to the lead-lag implementation, accounting forincomplete discharge of the second stack, in order to have a bufferbetween the constant output temperature and the discharge temperature ofthe second stack at its lowest point in the cycle. The ability of thesystem to discharge the second stack to the constant output temperaturedepends on variables such as weather forecast, season, length of solarday. The practice of incomplete discharge thus avoids the undesirabledischarge to below the constant output temperature. Features common toFIGS. 24-33 are given similar reference numerals.

Instead of having the temperature of the second stack fall precisely tooutput temperature 2065 c, the temperature may fall to a buffered amount2085 c that is slightly higher than the constant output temperature 2065c. In other words, the second stack does not completely discharge, butonly partially discharges. On the other hand, the first stack continuesto have the same temperature and air flow pattern as in FIG. 26 asexplained above.

The partial discharge may be accomplished by adjusting the flow 2084 cof the second stack, so that it is less than 100% of the total flow, forexample approximately 90%, e.g., 90%, of the total flow. To compensatefor the 10% of the total flow, the bypass is opened when the desiredsecond stack discharge (buffer) temperature 2085 c is reached, as shownat 2086 c. At 2087 c, the bypass and the second stack air flowessentially follow the air flow as shown above in FIG. 26 . The value of10% is just an example, and may be varied depending on the dischargetemperature, return air temperature, target heat content or targettemperature of the output, the flow percentage through each stack, aswell as the temperature of the stacks.

Similarly, during a second 24-hour cycle, the temperature of the firststack fall may fall to an amount 2085 c that is slightly higher thanconstant output temperature 2065 c. Thus, the first stack only partiallydischarges. The second stack has the same temperature and air flowpattern as described in FIG. 26 .

As with the first 24-hour period, the partial discharge may beaccomplished by adjusting the flow 2084 ca of the first stack, so thatit is less than 100% of the total flow, for example approximately 90%,e.g., 90%, of the total flow. To compensate for the 10% of the totalflow, the bypass is opened when the desired first stack dischargetemperature 2085 ca is reached, as shown at 2086 ca. As explained above,the value of 10% is just an example, and may be varied depending on thedischarge temperature, return air temperature, target heat content ortarget temperature of the output, the flow percentage through eachstack, as well as the temperature of the stacks. Accordingly, 2060Cillustrates that the control system is configured maintain an outputfluid flow at a specified constant temperature profile (2065 c), while,in successive discharge periods 2069 cd 1 and 2069 cd 2, alternatingbetween 1) deeply discharging the first stack while discharging thesecond stack to a first buffer temperature (2085 c) above the specifiedtemperature profile, and 2) deeply discharging the second stack whiledischarging the first stack to a second buffer temperature (2085 ca)above the specified temperature profile.

FIG. 28 provides a detailed illustration 2060D of a temperature andfluid flow according to the lead-lag implementation, accounting forcharging of the low-flow lag stack, in which air continues to betrickled through the first stack as it increases its dischargetemperature. The trickle may account for the possibility that the unitsare not sealed in such a manner that would permit 0% flow, and that thelouvers permit a residual flow, such as 5% or the like. While the valueof 5% is provided, it is noted that louvers generally cannot be closed100%, but can approach being ˜99%. The reason for this is because ofthermal expansion tolerances, differences between materials in thelouvers and bricks, and the like. The residual flow may approach 5%, andmay vary during the period, as shown in FIG. 28 . The louver is lessopen at beginning of charge to prevent entry of cooler air. As thecharge progresses, the residual flow is increased, as warmer air has aless negative impact due to the entry of the cooler air. Over time, theresidual flow may be increased to 5%, or even 10%. The upper bound maybe defined based on when trickle flow becomes prohibitively large suchthat hot spot gets hotter, as an example. Features common to previousFIGS. 24-33 are given similar reference numerals.

As with the operation described in FIG. 27 , the second stack undergoespartial discharge. But at the point at which the air flow of the secondstack reaches a maximum, here about 90% as shown at 2088 d, the air flowof the first stack is not completely shut off, but is instead kept at avery low rate or a trickle, such as about 5% or less (or in some cases,10% or less), as shown at 2089 d (thus operating in a “trickle mode”).To compensate for the flow at the first stack, the flow at the secondstack is decreased, as can be seen in the drawings. The trickle in thefirst stack prevents hot spots, because due to the buoyancy of the air,the hot spots will take more flow to be cooled at low flow. As a result,the possibility of thermal runaway may be avoided or reduced.

Similarly, in the second 24-hour period, at the point at which the airflow of the first stack reaches a maximum, here about 90%, e.g., 90%, asshown at 2088 da, the airflow of the second stack is not completely shutoff, but is instead kept at a very low rate or a trickle, such as about5% or less (for example, 5%), as shown at 2089 da. To compensate for theflow at the second stack, the flow at the first stack is decreased, ascan be seen in the drawings. Again, this mode may prevent or reduce thepossibility of thermal runaway.

Accordingly, 2060D illustrates that the control system is configured tomaintain a temperature 2065 d of the output fluid flow according to aspecified temperature profile (here, constant). This is accomplished byalternating, in successive discharge periods (2069 dd 1, 2069 dd 2),between 1) deeply discharging the first stack while discharging thesecond stack to a first buffer temperature (2085 d) that is above thespecified temperature, and 2) deeply discharging the second stack whiledischarging the first stack to a first buffer temperature (2085 da) thatis above the specified temperature. Furthermore, during discharge period2069 dd 1, fluid flow is maintained to the first stack in a tricklemode, while during discharge period 2069 dd 2, fluid flow is maintainedto the second stack in the trickle mode.

FIG. 29 provides a detailed illustration of a temperature and fluid flowaccording to the lead-lag implementation, accounting for variations inthe delivery temperature to reduce parasitic drag. Again, featurescommon to FIGS. 24-33 are given similar reference numerals.

As can be seen in the drawings, the output temperature may vary withinan acceptable range or the industrial application. (In some cases, a“specified temperature profile” may be a constant temperature, but asshown in FIG. 29 , the specified temperature profile is non-constant.)In this example, the initial constant temperature is 800° C. at 2090 e.But the temperature is later varied to a lower temperature such as 700°C. at 2091 e, by adjusting the flow as explained below.

As shown, in the first 24-hour cycle (2067 e), instead of having theflow through the first stack be 100% of the total flow as in FIGS. 24-33, the flow peaks at about 90%, e.g., 90%, of the total flow as indicatedby 2094E. Further, because the operating temperature is set at 800° C.,the necessity of bypass air is reduced from the start as shown at 2093 e(e.g., bypass air flow begins at approximately 20%, e.g., 20%, in FIG.29 as compared to approximately 40%, e.g., 40%, in FIG. 28 ).Additionally, instead of having the flow in the first stack begin from60% and increase to 100%, the flow here begins from about 75%, e.g.,75%, and increases to about 90%, e.g., 90%. To accommodate for theadditional 10% of flow, additional air begins flowing through the secondstack earlier than in previous examples. This, in turn, causes thesecond stack's discharge temperature to cool slightly earlier thanpreviously described.

As noted above, the flow through the first stack is maintained at about10%, e.g., 10%, during the charging phase of the first stack, asindicated by 2097 e. When the output temperature is varied to about 700°C., e.g., 700° C., at 2091 e, the discharge temperature of the secondstack also approaches about 700° C., e.g., 700° C., at 2092 e. Becausethe air flow of the first stack and the second stack are maintained at arelatively constant proportion during the charging phase (as indicatedby 2096 e and 2097 e, respectively), the discharge temperatures of thefirst and second stack behave in a similar manner as in the aboveexamples. During the latter part of the solar day, the bypass flow isincreased at 2095 e in order to cool the unit; the flow of the first andsecond stacks both decrease correspondingly.

In the second 24-hour cycle (2067 ea), the constant temperature of 800°C. is also varied to 700° C. by adjusting the flow, as indicated by 2090ea and 2091 ea. Again, instead of having the flow through the secondstack be 100% of the total flow as in the above-described examples, theflow is instead only increased to about 90% of the total flow asindicated by 2094 ea. Further, because the operating temperature is setat 800° C., the necessity of bypass air begins at a lower amount than inprevious examples. Similarly, instead of having the flow in the secondstack start from 60% and increase upward to 100%, the flow extends fromabout 75% to about 90%. To accommodate for the additional 10% of flow,additional air begins flowing through the first stack earlier than inprevious examples. The first stack's discharge temperature thus coolsslightly earlier than previously described.

As noted above, the flow through the second stack is maintained at about10%, e.g., 10%, during the charging phase of the second stack, asindicated by 2097 ea. When the output temperature is varied to about700° C., e.g., 700° C., at 2091 ea, the discharge temperature of thefirst stack also approaches about 700° C., e.g., 700° C., at 2092 ea.Because the air flow of the second stack and the first stack aremaintained at a relatively constant proportions (as indicated by 2096 eaand 2097 ea, respectively) the discharge temperatures of the first andsecond stack behave in a similar manner as in the above examples. Duringthe latter part of the solar day, the bypass flow is increased at 2095ea in order to cool the unit; the flow of the first and second stacksboth decrease correspondingly.

Accordingly, 2060E illustrates that different sets of flow parametersmay be used during a discharge period to change a temperature of anoutput fluid flow having a non-constant temperature profile.Furthermore, the output fluid flow temperature may be maintained duringa charging phase by keeping the fluid flows of the first and secondstack at a relatively constant proportion.

To recap, deep discharging is the discharging of a thermal storage stackto a sufficient degree to reduce local temperature nonuniformitieswithin the stack, and thus reduce, mitigate, or eliminate thermalrunaway within the stack (and thus extends its life). In some cases, aperiod of deep discharging may result in a stack being discharged allthe way to some temperature floor—namely, the temperature of the bypassfluid flow (the “bypass temperature”). As has been noted, the bypassflow is a flow of cooler fluid within the thermal storage structure—itmay be based, for example, on a fluid flow that enters the thermalstorage structure via an inlet valve. Accordingly, deep discharging mayin some cases cause a stack to be discharged all the way to the bypasstemperature or to a temperature approximately equal to the bypasstemperature (say, within 10% of the bypass temperature).

But as noted above relative to FIG. 24 , factors such as the peaktemperature and delivery temperature affect the amount that a particularstack may be cooled within a discharge period. Further, it may be thecase that any of a range of temperatures for a particular use case mayeffectuate deep discharge—e.g., deep-discharge temperature region 2063r. FIG-I-F is a block diagram 2098 c 1 that illustrates a range oftemperatures that can be used to define different deep-dischargetemperature regions for different situations.

As shown, the range of temperature has an upper bound of deliverytemperature 2065 u (here 600° C.), a lower bound of bypass temperature2063 lo (200° C.), and a midpoint temperature 2098 m (400° C.), which isthe midpoint between the delivery temperature and the bypasstemperature. Another temperature reference is shown, 2098 mm(300°),which represents a midpoint between the midpoint temperature and thebypass temperature, and thus may be referred to as a quartiletemperature. Nine possible temperatures are shown: 500° C. (2098 t 1),450° C. (2098 t 2), 360° C. (2098 t 3), 325° C. (2098 t 4), 275° C.(2098 t 5), 245° C. (2098 t 6), 215° C. (2098 t 7), 204° C. (2098 t 8),and 200° (2098 t 9).

Typically, the deep-discharge temperature region's upper bound will bebelow the delivery temperature. In the case in which the upper boundwere at, say 550° C., all 9 temperatures 2098 t 1-9 would be within thedeep-discharge temperature region. Alternately, if the deep-dischargetemperature region's upper bound were defined to be substantially belowthe delivery temperature, this might exclude just temperature 2098 t 1from the deep-discharge temperature region. Substantially below means atleast 20% below, and in other cases could be defined to be 25%, below30% below, 35%, 40%, 45%, and so on. Temperature 2098 t 2 is thus 25%below delivery temperature and could be included in the deep-dischargetemperature region depending on how the range is defined relative to thedelivery temperature. Note that the lower bound of the deep-dischargeregion can be set to the bypass temperature or some higher temperatureas desired.

Another way of defining the deep-discharge temperature region is thatthe upper end of the deep-discharge temperature region is closer to thebypass temperature than to the delivery temperature, and the lower endof the deep-discharge temperature region is the bypass temperature.Referring to chart 2098 c 1, this would mean that the upper bound wouldbe at midpoint temperature 2098 m (400° C.) (and for purposes of thisexample, the upper bound could include midpoint temperature 2098 m).This definition of the deep-discharge temperature region would includetemperatures 2098 t 3-2098 t 9, and exclude temperatures 2098 t 1-2098 t2.

Still another way of defining the deep-discharge temperature region isthat the upper end of the deep-discharge temperature region is closer tothe bypass temperature than to the midpoint temperature, and the lowerend of the deep-discharge temperature region is the bypass temperature.Referring to chart 2098 c 1, this would mean that the upper bound wouldbe at quartile temperature 2098 mm (300° C.) (and for purposes of thisexample, the upper bound could include quartile temperature 2098 mm).This definition would include temperatures 2098 t 5-2098 t 9, andexclude temperatures 2098 t 1-2098 t 4.

Still further, an upper bound of the deep-discharge temperature regioncould be defined as those temperatures that are approximately equal tothe bypass temperature. Thus, with “approximately equal” meaning within10% of the bypass temperature, this would include temperatures between200 and 220° C., encompassing 2098 t 7-2098 t 9.

Yet another way of defining the deep-discharge temperature region is todefine an absolute temperature range measured up from the bypasstemperature. Several ranges of this sort are shown in FIG. 33 . Range2098 r 1 encompasses the bypass temperature 2063 up to temperatures 25°C. warmer. Thus, if the bypass temperature were 200° C., range 2098 r 1would include 200° C., 225° C., and all temperatures in between.Similarly, range 2098 r 2 encompasses temperatures up to 50° C. warmerthan the bypass temperature. Ranges 2098 r 3-r 6 encompass temperaturesup to 75° C., 100° C., 150° C., and 200° C. above the bypasstemperature.

In a similar manner, although not shown, the upper bound of thedeep-discharge temperature may also be defined by establishing atemperature distance measured down from the delivery temperature. Forexample, a first range might have an upper bound of the deliverytemperature minus 100° C. and a lower bound of the bypass temperature. Asecond such range might have an upper bound of the delivery temperatureminus 125° C. and a lower bound of the bypass temperature. A third suchrange might have an upper bound of the delivery temperature minus 150°C. and a lower bound of the bypass temperature. A fourth such rangemight have an upper bound of the delivery temperature minus 175° C. anda lower bound of the bypass temperature. A fifth such range might havean upper bound of the delivery temperature minus 200° C. and a lowerbound of the bypass temperature. Other ranges are possible, such as asixth range in which the upper bound of the deep-discharge temperatureregion is the 300° C. below the delivery temperature.

FIGS. 24 through 33 have described implementations in which each of twothermal storage arrays are deeply discharged every other dischargeperiod. But this disclosure is not limited to thetwo-thermal-storage-array implementation. First of all, deep dischargingmay be performed when only a single thermal storage array is used. Insuch a configuration, the outlet temperature of the single thermalstorage array is allowed to drop to a deep-discharge temperature regionon a periodic basis or on an as-needed basis. In configurations withthree or more groups, deep discharging may be performed less frequently.

The preceding Figures have described implementations in which each oftwo thermal storage arrays are deeply discharged every other dischargeperiod. But this disclosure is not limited to thetwo-thermal-storage-array implementation. First of all, deep dischargingmay be performed when only a single thermal storage array is used. Insuch a configuration, the outlet temperature of the single thermalstorage array is allowed to drop to a deep-discharge temperature regionperiodically—either at regular intervals or on an as-needed basis. Inconfigurations with three or more groups, deep discharging may beperformed less frequently.

FIG. 30 is a block diagram illustrating definition of a deep-dischargetemperature based its relative closeness to two reference temperatures.FIG. 31 is a block diagram illustrating definition of a deep-dischargetemperature based on a difference from the bypass temperature. FIG. 32is a table illustrating an example in which each of N storage arrays(N=3) is deep-discharged once during every N discharge periods. FIG. 33is a table illustrating an example in which each of N storage arrays isdeep-discharged multiple times and partially discharged once duringevery N discharge periods.

Consider a configuration with N storage arrays. FIG. 30 illustrates anexample 2099 t 1 in which each of the N thermal storage arrays 2099 a isdeep-discharged once during every N discharge periods (2099 dp). Asshown, N=3 and the three arrays are referred to arrays 1, 2, and 3. Indischarge period 1, array 1 acts in a leading mode and array 2 acts in alagging mode. Accordingly, array 1 is deeply discharged and array 2 ispartially discharged. In a discharge period 2, array 2 acts in a leadingmode (and thus is deeply discharged) and array 3 act sin a lagging mode(and is thus partially discharged) (2099 p). Finally, in dischargeperiod 3, array 3 acts in leading mode (deeply discharged) and array 1acts in a lagging mode (partially discharged). Thus, two of the threestacks may discharge on a given day, while the other stack does not deepdischarge on that day. However, this arrangement may be varied.

Thus, in one generalization of a thermal energy storage system with somenumber N thermal storage assemblages, one possible implementation isthat each of the N assemblages (2099 a) is deeply discharged once (2099e) every N discharge periods (2099 dp).

Consider another embodiment illustrated by table 2099 t 2, in which N=3and again involves arrays 1, 2, and 3 (2099 a). At the end of a periodof VRE availability (e.g. The end of daytime for solar-charged systems),arrays 1 and 2 may complete the day fully charged; full heat is applied,properly by zone, without significant gas flowing through theirconduits. Array 3, however, is operated in a discharging mode with highgas flow in its conduits during charging.

Suppose that after charging stops, discharge period 1 begins, and array3 begins to discharge to provide output fluid flow. During the dischargeperiod, lower-temperature discharge fluid from array 3 is mixed withhigher-temperature fluid of array 1 to deliver the output fluid flow.Array 3 deeply discharges by cooling to a temperature that is close tothe return gas temperature. Then, when the discharge fluid temperatureof array 1 begins to decrease, significant flow through array 3 isterminated, and flow through array 2 is initiated. Mixing oflower-temperature fluid from array 1 with higher-temperature fluid fromarray 2 also allows array 1 to deeply discharge. In this example, nearthe end of the discharge period, flow from array 1 is terminated,leaving only array 2 in operation. Thus, array 3 and array 1 both deeplydischarge during discharge period 1, with array 2 partially discharging.

During the next cycle of discharging and charging, the operation of thearrays is rotated—thus, during discharge period 2, array 2 dischargesfirst, followed by array 3, and then array 1. Arrays 2 and 3, but notarray 1, are deeply discharged as a result. Similarly, during dischargeperiod 3, array 1 discharges first, its high-temperature energy beingmixed with other array discharges. As array 1 reaches its minimum usableoutlet temperature, array 2 begins to add higher-temperature gas, untilby the end of the discharge period, arrays 1 and 2 are deeply dischargedand array 3 has a temperature profile similar to conduit 2010 at pointin time 2051 in FIG. 23 . This approach allows each thermal storagearray to be deeply discharged two out of every three charging cycles.

The above-described processes have various advantages. For example, inthe two-array implementation for a solar use case, each stack is deeplydischarged every other day by flow control of the two stacks and abypass; accordingly, variations in temperature that would otherwisearise from nonuniform heating or cooling in the stack and cause thermalrunaway problems are avoided. Deeply discharging a stack causes it tothermally reset such that any nonuniformities that would otherwise causethermal runaway are avoided or reduced. Further, parasitic drag may beavoided by use of a blended output temperature.

While the foregoing aspects are disclosed in the context of a thermalstorage array having an internal resistive heating element to provideradiant heat transfer, the present disclosure is not limited to thisconfiguration. For example, the lead-lag approach of having stacksoperating in tandem with one stack in the lead mode and the other stackin the lag mode is also applicable in scenarios in which heat isexternally delivered by gas.

In various implementations, the control system is configured to provideone or more control signals to control various aspects of the thermalenergy storage system, including the louvers, the bypass valve and thefan or blower associated with the circulation of fluid through thethermal storage arrays. Additionally, instead of using a single blowerfor all thermal storage arrays, separate blowers may be provided foreach of the airflows, such as the flow of air to the first stack, theflow of air to the second stack, etc. In such an alternative, thecontrol system would control the blowers instead of controlling louvers.In other implementations, however, a combination of blowers and louversmay be used together to control the flow of air through the first stack,the second stack, and bypass to implement the lead-lag paradigm.

Operations Associated with System

The safe and effective start-up of an OTSG and steam network involvesseveral challenges. All equipment must be brought to operatingtemperature safely, without discharging sub-temperature fluid, includingwater, into the system outlet, as such discharges can cause substantial“steam hammer” damage and safety risks. The present innovation addressesthese matters to provide a safe, efficient start-up for an OTSG whoseheat source is a thermal energy storage unit. FIGS. 35(A)-(B) illustratean example flow 2200 of startup and shutdown sequences for the thermalenergy storage system as described herein. This example flow shows thestartup and shutdown of steam generation. While the operationsassociated with the startup and shutdown sequences are shown in anumerical order, in some cases the order of the operations may bemodified, and some operations may overlap or be done concurrentlyinstead of in sequential order.

At 2201, the outlet valve is in a closed position, or is set to a closedposition. As explained above, sensors and communication devicesassociated with the control system may sense the position of the outletvalve, and if the outlet valve is not in the closed position, thecontrol system may send a signal to the outlet valve, such that theoutlet valve is transited to the closed position.

At 2203, the blowdown valve is opened. In a manner similar to thatexplained above with respect to 2201, the blowdown valve may be moved tothe open position, if not already in the open position. A blowdown valveallows release of water and/or steam whose temperature or quality isbelow the temperature and/or quality required, without introducing therequirement of recirculation of fluid within the OTSG system.

At 2205, operation of a water pump is started, and low water flow isestablished. The conduits of the steam generator are now receiving waterin liquid form.

At 2207, the operation of the fan associated with the thermal storagestructure is started. For example, the fan may be the blower asexplained above. Accordingly, a low hot air flow is established. Heat isthus introduced to the tubes. The previous establishment of water flowwithin the tubes prevents thermal damage.

At 2209, as the low hot air flows, and the low water flow is establishedthrough the steam generator, the water is heated, and steam starts toform from the heated water, as the water changes phase from liquid togaseous form.

At 2211, as the hot air continues to flow and the heating of the steamgenerator continues, the pressure of the steam increases, and the vaporfraction or quality of the output steam rises.

At 2213, once the quality of the steam is above a threshold, such as40%, the outlet of the steam generator opens and the blowdown valvecloses. At this point, the steam may be output to the industrialapplication without the risk of introducing water or sub-quality steaminto the application network.

At 2215, as the outlet opens and the steam generator continues toprovide steam, the quality and flow of the steam rise to the requiredlevel for the industrial application associated with the output. Thisincrease in flow rate may be at a rate chosen so as to allow the rate ofchange of other steam generators serving the same industrial load toreduce their flow rates proportionally; or at a rate chosen to match thedeclining steam production rate associated with shutting down afuel-fired heater; or at another rate.

In some implementations, as steam or heat output from a thermal storageunit begins, a controller reduces the steam or heat output of one ormore fuel-fired heaters (boilers, OTSGs, HRSGs, furnaces) which servethe same industrial process load, in such a manner as to maintain anapproximately constant total steam supply to the industrial load.

Additionally, with respect to the shutdown sequence, at 2202, the fantransits from the on state to the off state. For example, the air blowermay stop its operation.

At 2204, the water pump slows or reduces the flow of liquid water to theconduits of the steam generator.

At 2206, as the flow of heat slows, and the flow of water slows, thequality of steam drops. For example, the quality of steam may drop to alower quality level, such as 50% or 60%.

At 2208, once the quality of steam has dropped below a prescribed level,the outlet valve returns to the closed position. Thus, the industrialapplication is no longer receiving steam, as the quality of steam hasdropped below the necessary level for the industrial application.

At 2210, the water pump pumps water into the tubing so that the tubingor conduit of the outlet is completely filled with water.

At 2212, the natural circulation of air within the thermal storagestructure continues to maintain the dynamic cooling associated with theouter wall invalidation, as explained above.

Advantages

The example implementations may have various advantages. For example, asexplained above, there is a dynamic insulation approach, which providespassive cooling of the thermal storage structure. The incoming cool airabsorbs the heat on the outside of the insulation layer, and iseventually passed into the lower portions of the stacks of bricks. As aresult, the heat is not transferred to the outer surface of the thermalstorage structure. The thermal storage structure can thus houseequipment having a wider temperature tolerance. Further, there is lowerrisk of equipment damage, wear and tear, system failure, injury to thepersonnel, or other safety issue associated with the presence of heat atthe surface of the outer container.

Further, the present disclosure contemplated the use of recirculated airto provide cooling for the thermal storage structure, thus eliminatingor reducing the need for a secondary cooling system. During shutdownperiods, passive buoyancy-induced flow continues so as to providefoundation cooling without backup power or special equipment. Thisprovides an advantage over thermal energy storage systems using moltensalt which require active cooling of the foundations of the molten salttanks, provided by blowers that add to cost and to parasitic electricpower consumption and require redundant diesel generator backups. Bycooling the foundation as described in this disclosure, energy that wasotherwise lost in prior systems is captured as useful energy, andthermal safety in all conditions is provided.

Additionally, there is an environmental benefit over previousapproaches. Because the control system allows the thermal energy storagesystem to use the source electricity based on the daily supply anddemand of energy, the source electricity that is produced when thesupply exceeds the demand can be used for storage during the chargingmode. When the demand exceeds the supply, the thermal energy storagesystem can discharge and provide electricity or outputs for otherindustrial applications to support the additional demand. This paradigmdesirably reduces the need to use nonrenewable energy. Further, variousindustrial applications such as calcining, carbon capture and others maybe performed using heat derived from renewable energy sources ratherthan nonrenewable sources. As a result, the generation of carbon dioxideor other greenhouse gases may be reduced.

In terms of efficiency and cost, the various implementations describedin the present disclosure provide a more efficient approach to managingenergy input and output. FIGS. 34(A)-(C) illustrate various energy inputand output curves 2100 associated with solar energy generation. In chart2101, an example energy input and output graph over a daily period isshown. Curve 2105 shows the available power. For example, during thetime of day when solar energy is available, such as between 4 AM and 8PM, the available power is illustrated as 2105. At 2103, the availablecharging power is shown. As can be seen at 2107, the available chargingpower may reflect the power available. At 2103, steam delivery is shown,which reflects the energy that is output or produced. At 2109, theactual electricity generated to the customer by the solar energy isshown.

Charts 2111 and 2121 compare daily power profiles for different seasons.Chart 2111 illustrates a power profile during a winter day, while chart2121 illustrates a power profile during a summer day. At points 2115 and2117, it can be seen that on a winter day, the power available veryroughly corresponds to the charging power. At 2125 and 2127, it can beseen that for a portion of the day the power available corresponds tothe charging power, but during the afternoon of the summer day, thecharging power is substantially lower than the available power. Asexplained above, the “day” is defined as a diurnal solar cycle thatbegins with the time of sunrise and ends with the time of sunset; it isunderstood that the time of sunrise and sunset can vary depending onphysical location in terms of latitude and longitude, geography in termsof terrain, date, and season. At 2119 and 2129, the actual electricitygenerated to the customer by the solar energy is shown. At 2113 and2123, steam delivery is shown, which reflects the energy that is outputor produced.

At 2131 and 2141, a comparison is provided, for a summer day, ofnon-deferred charging at 2131, and deferred charging at 2141, such asassociated with the example implementations. The elements of 2131roughly correspond to the elements of 2121 and 2101. By comparison, at2141, with deferred charging, it can be seen that the charging power2147 can very roughly match the power available on a summer day duringthe afternoon periods. Thus, the example implementations can usedeferred charging to use the available power more efficiently.

The lifetime of the system components and the efficiency of energystorage may benefit from maintaining the storage core at a lowertemperature; however, doing so reduces the amount of energy storagecapacity. A thermal energy storage system in which the electricalheaters are embedded within the storage media core causes the heaters toremain at the media temperature over extended periods; and the long-termtemperature exposure of the heaters is a key factor in their operatinglife. An innovation presented here contributes to extended heater andequipment life, by mitigating the annual average temperature thatheaters experience. In the case where the storage unit is operated toprovide a continuous supply of heat from a variable source, a controllermay choose a state of charge below “full charge” on a daily basis, basedon forecast energy availability and planned energy demand. For example,in a system powered by solar energy, summer days are longer, so asmaller number of hours of stored energy are required; hence inmidsummer the storage unit may be operated by a controller to remain ata lower temperature (or “partial charge”) so as to extend system lifeand reduce thermal losses, without any reduction in energy delivered tosystem output. And, for example, in a system powered by solar energy,winter days have lower total energy available, so that the entire energyproduced by an associated solar facility can be stored using only aportion of the storage capacity. A controller may operate the storagesystem in these conditions to maintain only partial charge, again so asto extend system life, without any loss of energy delivery at the systemoutput. Various advantages are provided by other features of the overallsystem, including those relating to the arrangement of thermal storagearrays, as well as the constituent thermal storage blocks. Thosefeatures are the subject of the next Section.

Additionally, the present example implementations mitigate thermalstress effects in several ways. The present disclosure mitigates thermalstress arising from thermal expansion due to rapid heating and coolingby partitioning the storage media into bricks of a size and shape whichenables rapid radiative heat transfer while maintaining thermal stresslevels and patterns within the bricks below levels which induce promptor gradual failures. Heat transfer flow conduits and flow rates arearranged such that turbulent flow of heat transfer gas providesrelatively uniform cooling across the entire exposed heat transfersurface. The storage media bricks are arranged in an array that allowsrelative movement to accommodate expansion and contraction by individualelements. Also, the array is arranged such that cycles of thermalexpansion align the elements of the array to preserve the integrity ofthe array structure, the integrity of the heating element conduits, andthe integrity of the heat transfer gas conduits.

In some example implementations, individual bricks are designed suchthat their center of mass is close to a heating element, and an expandedsurface area allows high contact with flowing air.

II. Heat Transport in Tsu: Bricks and Heating Elements

A. Problems Solved by One or More Disclosed Embodiments

Traditional approaches to the formation of energy storage cells may havevarious problems and disadvantages. For example, traditional approachesmay not provide for uniform heating of the thermal energy storage cells.Instead, they may use structures that create uneven heating, such as hotspots and cold spots. Non-uniform heating may reduce the efficiency ofan energy storage system, lead to earlier equipment failure, causesafety problems, etc. Further, traditional approaches may suffer fromwear and tear on thermal energy storage cells. For example, stressessuch as mechanical and thermal stress may cause deterioration ofperformance, as well as destabilization of the material, such ascracking of the bricks.

B. Example Solutions Disclosed Herein

In some implementations, thermal storage blocks (e.g., bricks) havevarious features that facilitate more even distribution. As one example,blocks may be formed and positioned to define fluid flow pathways withchambers that are open to heating elements to receive radiative energy.Therefore, a given fluid flow pathway (e.g., oriented vertically fromthe top to bottom of a stack) may include two types of openings:radiation chambers that are open to a channel for a heating element andfluid flow openings (e.g., fluid flow slots) that are not open to thechannel. The radiation chambers may receive infrared radiation fromheater elements, which, in conjunction with conductive heating by theheater elements may provide more uniform heating of an assemblage ofthermal storage blocks, relative to traditional implementations. Thefluid flow openings may receive a small amount of radiative energyindirectly via the chambers, but are not directly open to the heatingelement. The stack of bricks may be used alone or in combination withother stacks of bricks to form the thermal storage unit, and one or morethermal storage units may be used together in the thermal energy storagesystem. As the fluid blower circulates the fluid through the structureduring charge and discharge as explained above, a thermocline may beformed in a substantially vertical direction. Further, the fluidmovement system may direct relatively cooler fluid for insulativepurposes, e.g., along the insulated walls and roof of the structure.Finally, a venting system may allow for controlled cooling formaintenance or in the event of power loss, water loss, blower failure,etc., which may advantageously improve safety relative to traditionaltechniques.

The present teaching is an advance in exploiting the physics of heattransfer to enable the cost-effective construction of thermal energystorage systems. Compared to prior art using solid media, designsaccording to the present disclosure reduce reliance on and improve thereliability of conductive heat transfer; deliver uniformhigh-temperature heat via convective heat transfer; and principallyexploit direct radiative heat transfer, with heat radiating from aheating element and reradiating from heated storage materials(“radiation echoes”) to heat other storage materials rapidly anduniformly.

All objects in the universe emit thermal radiation at a rateproportional to their absolute temperature to the fourth power.Specifically, per the Stefan-Boltzmann law, the total energy radiatedper unit surface area of a black body per unit time is proportional tothe fourth power of the black body's thermodynamic temperature (inkelvin). Accordingly, small differences in temperature cause largedifferences in the rate of thermal radiation.

All objects in the universe also absorb thermal radiation. For any twosurfaces exposed only to each other, and absent any incoming or outgoingheat, the differences in temperature between such objects exposed toeach other rapidly reduce until the objects are at the same temperature,and thus in radiation equilibrium.

It is desirable for a system based upon electrical heating elements thatheat solid media to operate heaters at a relatively high powerloading—that is, to operate with high wattage per square cm of surfacearea. Doing so reduces the amount of heating material and cost per unitof charging energy (cost per kW). However, heating element life variesinversely with temperature, so in order to maximize power loading whilekeeping heating element temperatures as low as practicable, it isaccordingly desirable for heaters to radiatively expose materials of thelowest and most uniform surface temperatures possible.

In some existing designs, e.g. residential “storage heaters” and Stackdisclose designs, heaters are exposed to only a relatively small surfacearea, for instance by being embedded in channels. Prior art based onStack's teachings and related designs can be expected to suffer greatlyfrom any nonuniformity in brick size, internal structure, or materialcomposition, since the only means by which surface temperature iscontrolled is by internal conduction of heat away from the outer surfaceinto the inner material.

Variations in aggregate content within the brick itself can contributeto varying thermal conductivity. Such variations in heat conduction willnecessarily result in variations in surface temperature if incomingradiation is heating the surface, and such variations will besignificant if thermal radiation is unable to carry awayhigher-temperature energy to lower-temperature regions. Moresignificantly, any cracks formed within a brick can cause greatreduction the thermal conductivity across the crack, and consequently ifthe brick is being radiatively heated this will reduce heat conductionaway from the surface, and thus cause regions of higher surfacetemperature unless thermal radiation can carry away such energy. Adesign based on, e.g., the Stack design would experience large increasesin surface temperature in both these cases, as only relatively small,local surface areas are in radiation communication due to the “channel”design concept. Mitigating these problems incurs costs. Because brickwith higher thermal conductivity is more expensive than brick with lowerthermal conductivity, and because electrical heating elements areexpensive, previous teachings have had serious limitations inpractically achievable temperatures and challenges in material usage(heater material usage per kW) and per kWh (storage material usage perkWh), due to requiring average temperatures be low enough to accommodatesuch local variations. Such previous designs are vulnerable to in-fieldfailures arising from brick cracking contributing to heater failures.Any such crack formation would require reducing or ceasing the poweringof heaters in the zone with cracking—as replacement heaters installed atthat location would continue to experience such abnormaltemperatures—and/or disassembly of the TSU and replacement of crackedbricks, both of which are quite impractical from a cost point of view.In consequence, units of such design would be vulnerable to degradationin their usable storage capacity and charging rate.

It is also desirable for systems that heat solid media to avoid hightemperature gradients within the solid media, as differential expansionbased on temperature results in stresses that may cause cracking ordegradation of the media as it successively heats and cools duringcharging and discharging operations, with resulting large time-varyingstress patterns. In designs in which heaters are exposed to only arelatively small surface area, only a relatively small fraction of thebulk material is heated by radiation, and a large proportion of theheating is accomplished via heat conduction within the material. Asconductive heating is proportional to ΔT within the material, perNewton's law of cooling, the rapid heating required in VRE-chargedstorage media creates significant potential for such systems toexperience degradation and cracking from thermally induced stresses. Inthis sense, a desired property for heater designs—high wattage per unitof surface area—is intrinsically in conflict with a desired property forbrick designs—low wattage per surface area—when heaters are installed inchannels or narrow passages such as taught by Stack and “storageheaters”.

It is further desirable for systems that deliver high-temperature heatfrom solid media to achieve “thermocline” conditions during discharge,in which portions of the media are cooled to much lowertemperatures—releasing more energy per kg of material—than otherportions, which remain at high temperatures—thus allowing the deliveryof relatively high continuous outlet temperatures throughout an extendedperiod of discharging while the bulk of the storage media swings acrossa large change in temperature (ΔT). In service of this goal, convectiveheat transfer by flowing air which is heated effectively and comes intobalance with local media temperature as it flows through successiveregions of material is advantageous. An example of such effectivethermocline design is the Cowper stove, which incorporates a pluralityof long narrow vertical air passages within a brick array, inducingturbulent airflow within the passages and thus effective heat transferbetween air and adjacent brick in each zone as air proceeds through thematerial. Provisions that prevent the transfer of heat via radiationfrom relatively hotter zones to cooler zones are desirable, as suchdownward vertical radiative heat flow would decrease the temperaturedifferential between the bottom and the top of the thermocline, reducingits effectiveness and thus lowering the available stored energy per unitof material. The Cowper stove's narrow air passages limit the mutualradiative exposure of surfaces in the vertical axis (due to cos Θ), andthus the Cowper stove design satisfies both these criteria for effectivethermocline design.

However, the Cowper stove design contains a liability. The air passagesin Cowper stoves are comprised of many bricks stacked vertically withinthe unit, each of which has a plurality of passages which must beproperly aligned with their corresponding passages in bricks above andbelow during assembly. Any misalignment during assembly, or due tocyclic thermal expansion and contraction during operation, causesblocking of flow through the passages. Any cracking or spalling ofbrick, or any introduction of foreign material that introduces materialwithin a passage at any point causes the blockage of flow in the entirepassage. In a Cowper stove design, in which the system is heated andcooled convectively, this causes a partial loss of heat storagecapacity, as such region is neither effectively cooled nor effectivelyheated. However, in an electrically radiant heated energy storage unit,such blockages of airflow have greater consequence, as they cause largereductions in cooling during discharge, but no reductions in incomingthermal radiation from heaters. Accordingly, passage blocking can causelarger consequences in electrically heated energy storage units, becauseas discussed above, variations in unit temperature can contribute topremature heater or brick failures, and in consequence an entire unitmay have to be operated at a lower temperature so that the peaktemperatures associated with the nonuniformity do not exceed safematerial operating temperatures.

Some designs, e.g. Siemens ETES, incorporate unstructured media withrandomly distributed air passages, causing zones of higher and lowertemperature air to mix, and allowing low-temperature air to bypassregions of high temperature solids without being heated, thus reducingthermocline effectiveness and increasing the amount of solid mediarequired to deliver a given amount of thermal energy while maintaining atarget outlet temperature, increasing storage media usage per kWh.

Designs according to the present disclosure combine several keyinnovations, which together address these challenges and enable acost-effective, safe, reliable high-temperature thermal energy storagesystem to be built and operated. A carefully structured solid mediasystem according to the present teaching incorporates structured airflowpassages which accomplish effective thermocline discharge; repeatedmixing chambers along the direction of air flow which mitigate thethermal effects of any localized air channel blockages ornonuniformities; effective shielding of thermal radiation frompropagating in the vertical direction; and a radiation chamber structurewhich uniformly and rapidly heats brick material with high heater powerloading, low and uniform exposed surface temperature, and long-distanceheat transfer within the storage media array via multi-step thermalradiation.

Innovative structures according to the present disclosure may comprisean array of bricks that form chambers. The bricks have structured airpassages, such that in the vertical direction air flows upwards in asuccession of open chambers and small air passages. In some embodiments,the array of bricks with internal air passages is organized in astructure such that the outer surface of each brick within the TSU coreforms a wall of a chamber in which it is exposed to radiation from otherbrick surfaces, as well as radiation originating from an electricalheater.

The chamber structure is created by alternating brick materials into acheckerboard-type pattern, in which each brick is surrounded on allsides by open chambers, and each open chamber has adjacent bricks as itswalls. In addition, horizontal parallel passages are provided that passthrough multiple chambers. Electrical heating elements that extendhorizontally through the array are installed in these passages. Anindividual heating element it may be exposed along its length to theinterior spaces of multiple chambers. Each brick within such acheckerboard structure is exposed to open chambers on all sides.Accordingly, during charging, radiant energy from multiple heatingelements heats all outer surfaces of each brick, contributing to therapid and even heating of the brick, and reducing reliance on conductiveheat transfer within the brick by limiting the internal dimensions ofthe brick.

Such a chamber structure further provides that a first portion of theheat that emanates from an electric heating element is absorbed by agiven first brick surface and further transferred by conductive heattransfer within the brick, thus heating that brick; and another portionof the heat is absorbed by a second brick surface relatively closer tothe heater than the first brick surface, raising the temperature of thatsecond brick surface. Because the second brick surface grows hotter thanbrick surfaces farther away from the heater the second brick surfaceradiates heat to those farther brick surfaces due to the temperaturedifferential. This process of radiation absorption of bricks, leading totemperature rise, and thence leading to increased thermal radiation, isreferred herein as “reradiation.” The reradiation of thermal energythroughout the brick stacks is an important factor in the rapid, evenheating of bricks. The structure is arranged such that heating elementsare radiatively exposed to passages that extend in a horizontaldirection, achieving relatively uniform heating across a givenhorizontal layer tier of bricks, while inhibiting radiative heating fromthe heating elements in a vertical direction, thus achieving andallowing persistent of an advantageous vertical thermocline.

The radiation chamber structure provides a key advance in the design andproduction of effective thermal energy storage systems that are chargedby electrical energy. The large surface area, which is radiativelyexposed to heaters, causes the average temperature of the large surfaceto determine the radiation balance and thus the surface temperature ofthe heater. This intrinsic uniformity enables a high wattage per unitarea of heater without the potential of localized overheating. Andexposed brick surfaces are larger per unit of mass than in priorsystems, meaning that incoming wattage per unit area is correspondinglysmaller, and consequently thermal stresses due to brick internaltemperature differences are lower. And critically, re-radiation ofenergy—radiation by hotter brick surfaces that is absorbed by coolerbrick surfaces—reduces by orders of magnitude the variations in surfacetemperature, and consequently reduces thermal stresses in brickmaterials exposed to radiant heat. Thus, the radiation chamber designeffectively enables heat to be delivered relatively uniformly to a largehorizontally oriented surface area and enables high wattage per unitarea of heater with relatively low wattage per unit area of brick.

Note that while this configuration is described in terms of “horizontal”and “vertical”, these are not absolute degree or angle restrictions.Advantageous factors include maintaining a thermocline and providing forfluid flow through the stack in a direction that results in convectiveheat transfer, exiting the stack at a relatively hotter portion of thethermocline. An additional advantageous factor that may be incorporatedis to position the stack in a manner that encourages buoyant, hot air torise through the stack and exit at the hot end of the thermocline; inthis case, a stack in which the hot end of the thermocline is at ahigher elevation than the cold end of the thermocline is effective, anda vertical thermocline maximizes that effectiveness.

By arranging the chambers with a relatively high aspect ratio andpredominantly horizontal axis, thermal energy is transferred by multiplesteps of reradiation to regions of brick that extend far from theheating element; and as the bulk storage temperature rises, the effectof the ° K{circumflex over ( )}4 (the fourth power of the thermodynamictemperature) thermal radiation drives a very strong “temperatureleveling” effect. That is, the hotter the cell becomes, the smaller thedifferences between the hottest and coolest portions of the cell. As aresult, the charging heat transfer within the brick array becomes moreeffective as temperature rises, and the entire media structure is heatedto a uniform temperature with a much smaller total amount of heatingelement than would be required in a design without a radiative heattransfer structure. This is in sharp contrast to previous teachings,including Siemens and Stack, which can be expected to experience lowerheat transfer effectiveness relying on conductive ΔT, which diminishesas bulk storage media temperature rises.

An important advantage of this design is that uniformity of heatingelement temperature is strongly improved in designs according to thepresent disclosure. Any variations in brick heat conductivity, or anycracks forming in a brick that result in changed heat conductivity, arestrongly mitigated by radiation heat transfer away from the locationwith reduced conductivity. That is, a region reaching a highertemperature than nearby regions due to reduced effectiveness of internalconduction will be out of radiation balance with nearby surfaces, andwill as a result be rapidly cooled by radiation to a temperaturerelatively close to that of surrounding surfaces. As a result, boththermal stresses within solid media, and localized peak heatertemperatures, are reduced by a large factor compared to previousteachings.

Equally important, the effect of any brick spalling, cracking, or theintroduction of foreign materials within air passages is greatlyminimized. An individual brick that experiences the blocking of apassage will experience reduced cooling during discharge cycles, and itssurface and internal material will remain hotter than adjacent areas,and thus such an area will effectively store less energy, as energystorage is proportional to ΔT. Because the surface of the brick is inradiative communication with other bricks via the open radiationchamber, radiation will transfer heat from such blocked-passage area toother bricks. Thus, the final ΔT experienced in a heating-cooling cyclefor a design with open radiation cavities will be larger than the ΔT forany design, such as Cowper stoves or Stack, that does not incorporatethis concept. The effect of any brick spalling, cracking, orintroduction of foreign materials into an air passage is furtherminimized due to the flow of air in the vertical axis during discharge.The presence of the radiation chambers eliminates any effect of passageblocking in one brick from affecting flow within the brick above it orbelow it, since air freely mixes in the chambers between bricks.Similarly, misalignments between bricks in the vertical direction cannotcause air passage blockage, as the narrow air passages in bricks are notin contact, but separated by open chambers.

Overview

As explained in the foregoing discussion, a system for thermal energystorage is provided that includes an input of electrical energy from asupply, one or more thermal storage units, and a fluid output (which maybe or include a gas), such as steam and/or heat, to an application. Asexplained above, the supply may be an energy source, such as one or morephotovoltaic cells. Other energy sources may be employed in combinationwith or substitution for the photovoltaic cells.

The electrical power sources may be any one or a combination of VREpower sources including wind and solar power, less variable renewablesources including hydroelectric and geothermal power, or other powersources including thermal power plants powered by coal, oil, gasnuclear, or any other method of electrical power generation that mightbe apparent to a person of ordinary skill in the art.

The thermal storage units may each include one or more heating elements(e.g., resistive heating elements) controlled by switches that manageand enable the heating elements to receive the electrical energy fromthe input, and an energy storage structure such as a brick. A fluidmovement system, (e.g., one or more blowers that may be oriented to pushfluid unto the system or pull fluid from the system) directs fluidthrough fluid flow paths in the thermal storage units.

The energy storage structure includes tiers of thermal storage blocks.For example, a first tier of thermal storage bricks may be arranged inan alternating pattern, such that a gap is formed between adjacent orneighboring bricks. A second tier of bricks is positioned adjacent tothe first tier, also in an alternating pattern with a gap formed betweenadjacent or neighboring bricks. The first tier of bricks and the secondtier of bricks are positioned with respect to one another such that thegaps of the first tier bricks are adjacent to the second tier bricks,and the gaps of the second tier bricks are adjacent to the first tierbricks.

One or more of the first-tier bricks in the second-tier bricks may haveairflow channels formed therein. More specifically, the airflow channelsmay be formed as apertures, holes, conduits or slots. For example, theairflow channels may be formed as an elongate slot, with a longerdimension being nonparallel to a surface of each brick that is adjacentto a gap. In some implementations it may be advantageous for the airchannels to have their longer dimension substantially orthogonal to asurface of each brick that is adjacent to a gap. In otherimplementations it may be beneficial for the air channels to have theirlonger dimension substantially parallel to a surface of each brick thatis adjacent to a gap.

Because the air channels have one axis of short dimension oriented asexplained above, turbulent flow may be induced, contributing toeffective heat transfer between air and the brick as it passes throughthe brick. Accordingly, a benefit of the slot arrangement may be a moreeffective cooling of each brick as air passes through the brick, andconsequently a more effective thermocline during discharging.

The airflow channels and the gaps between adjacent or neighboring bricksare formed in such a manner as to create airflow paths. Morespecifically, a first air flow path extends through the airflow channelsof a first-tier brick and a second-tier gap adjacent to the first tierbrick, and a second air flow path extends through the airflow channelsof the second-tier brick and a first tier gap adjacent to the secondtier brick.

The heater or heating element, which may be a resistive heating elementcoupled to the input of electrical energy from the supply in a meanswhich includes at least one control switch which may adjust input powerto any fraction of the currently available power, is positioned adjacentto the first tier of bricks and the second tier of bricks. For example,the heating element may extend parallel to a longitudinal direction ofthe tiers of thermal storage bricks. According to one exampleimplementation, the heating element extends laterally in a curvilinearpattern, between rows of the plurality of blocks.

According to one example implementation, the second tier may bepositioned above the first tier, such that the airflow paths aresubstantially vertical. However, the example implementations are notlimited thereto, and other spatial arrangements between the first tierand the second tier as may be understood by those skilled in the art maybe used in substitution or combination with the substantially verticalair flow paths.

Further, while the foregoing example implementation discloses a firsttier and a second tier, the present example implementation is notlimited thereto. For example, one or more additional tiers may beincorporated with the first tier and the second tier, to form additionalalternating patterns having gaps and airflow channels. Further, thebricks in each of the additional tiers may be positioned to formadditional portions of the first and second airflow paths, such that theadditional airflow paths extend through airflow channels of a brick, andthrough a gap of a tier adjacent, such as above or below, the brick.

In the foregoing multiple tiers of bricks, the dimensions of the bricksmay be varied, such that the tiers at or closer to an upper portion ofthe stack may be larger in at least one dimension, such as height, ascompared with bricks at or closer to a lower portion of the stack. Byhaving such variation in the dimensions of the bricks, brick size may beoptimized to account for greater weight loads near the lower portion ofthe stack, and/or higher air temperatures closer to the upper portion ofthe stack. Example, bricks in the upper layers may be taller than thebricks in the lower layers. The reason for this is because as gas isconstantly flowing in at the bottom of the stack and cooling the lowerlevels, more heat power is needed per unit mass to heat the bricks nearthe bottom of the stack.

More specifically, the heat from the heating element is not only heatingup the brick itself, but also heating the gas within the volume of thebrick up to a desired temperature. Moving vertically toward the upperportion of the staff, the same heater may heat larger bricks, becausethe bricks do not have the same incoming air that needs to the heated asthe bricks near the bottom of the stack. Moreover, the heaters have acertain amount of power that they are capable of outputting, such thatthe heaters at the upper and lower portions of the stack may have aheater with similar or same power output. Thus, the cavities may betaller towards the upper portion of the stack, because the entering airhas already been heated by the bricks at the lower portion of the stack,and the energy from the heating elements is heating up the mass of thebrick itself, as opposed to the air within the volume of the mass of thebrick.

In some implementations, a control system for the heater elements isconfigured to power heater elements at one or more different levelsindependently, e.g., to output more or less energy depending on theheight (e.g., tier) of the heater elements in the assemblage.

Multiple stacks of bricks may be arranged adjacent to one another toform a thermal storage unit. Similarly, multiple thermal storage unitsmay be arranged adjacent to one another to form the thermal energystorage system.

Example implementations may also provide an efficient and reliablethermal storage system that involves use of multiple thermallyconductive and absorbing bricks being stacked together to form thermalenergy storage cells having sizes and material compositions chosen tomitigate thermal stresses. The thermal storage system may also maintaina constant temperature profile across the length of the cells (stackedbricks) thereby slowing temperature ramp, and reducing the generation ofhot and cold hot spots, mechanical stress, thermal stress, and crackingin the bricks.

In some example implementations, the system may include multiple cellsto form a thermal unit. The system may include multiple cells, each cellbeing made of multiple stacks. During charging, a controller may providepower flowing at different rates at different times selectively toindividual heating elements or groups of elements so as to control therate of heating of specific subsections of stacks, or specific stackswithin the unit, or specific sections (e.g., specific bricks or sectionsof bricks within a stack.

For example, if only 60% of maximum energy capacity is anticipatedduring a specific charging cycle, only elements in 60% of stacks or in60% of bricks in the system may be heated. The selective heating ofspecific heating elements may ensure that 60% of bricks achieve maximumtemperature during the charging period, instead of heating all of theelements causing 100% of bricks being heated to 60% of maximumtemperature.

Such a charging configuration may have various benefits and advantages.For example, the efficiency discharge of energy during a dischargingoperation may be substantially increased.

The system may include one or more air blowing units including anycombination of fans and, blowers, and configured at predefined positionsin the housing to facilitate the controlled flow of air between acombination of the first section, the second section, and the outsideenvironment. The first section may be isolated from the second sectionby a thermal barrier. The air blowing units may facilitate the flow ofair through at least one of the channels of the bricks from the bottomend of the cells to the upper end of the cells in the first section atthe predefined flow rate, and then into the second section, such thatthe air passing through the bricks and/or heating elements of the cellsat the predefined flow rate may be heated to a second predefinedtemperature, and may absorb and transfer the thermal energy emitted bythe heating elements and/or stored by the bricks within the secondsection. The air may flow from the second section across a steamgenerator or other heat exchanger containing one or more conduits, whichcarry a fluid, and which, upon receiving the thermal energy from the airhaving the second predefined temperature, may heat the fluid flowingthrough the conduit to a higher temperature or may convert the fluidinto steam. Further, the system may facilitate outflow of the generatedsteam from the second end of the conduit, to a predefined location forone or more industrial applications. The second predefined temperatureof the air may be based on the material being used in conduit, and therequired temperature and pressure of the steam. In anotherimplementation, the air leaving the second section may be deliveredexternally to an industrial process.

Additionally, the example implementations described herein disclose aresistive heating element. The resistive heating element may include aresistive wire. The resistive wire may have a cross-section that issubstantially round, elongated, flat, or otherwise shaped to admit asheat the energy received from the input of electrical energy.

With regard to the composition of the resistive heating element, if theresistive heating element is a resistive wire, it may be metallic.Further, the resistive heating element need not be limited to metallicwire, and may instead be formed from another material, such as aceramic, including but not limited to silicon carbide, magnesiumsilicide, or may be formed from a combination of these and/or othermaterials.

Bricks and Stacks

Example implementations of the energy storage system include a housingcomprising at least two sections (also referred to as cells) which maybe fluidically coupled to each other. A first section may include one ormore thermally conductive bricks of being stacked together with eachother to form a thermal storage cell within the housing. Note that someblocks may be relatively large and include multiple portions (e.g.,rectangularly-shaped brick portions). Thus, a given block may includeportions on multiple tiers and may cover multiple chambers. A heatingelement may be suspended from a support within a passage within thearray, or may mechanically form part of the array itself (as, forexample, a conductive ceramic material formed as one or more brickswithin the array), or may be positioned adjacent to the array (as, forexample, a heating element such as a tungsten or xenon elementencapsulated in a material which is at least partially transparent toelectromagnetic radiation in the infrared and visible spectrum).

One or more of the bricks may include at least one channel extendinglongitudinally between two opposite ends of the bricks. Accordingly, atleast one of the channels of each of the stacked bricks corresponding toone of the cells are in line with each other. Alternatively, suchchannels by be arranged such that adjacent bricks channels are arrangedtogether to create a channel. A number of bricks may be stacked over oneanother to form an assemblage of the required height. The height of thecells may be selected considering the height of the housing. Further,the dimension of the bricks that are stacked over one another may be thesame, or it may be different. For example, the bricks and an upperportion of the cell may have a greater height than the bricks at a lowerportion of the cell.

The system includes at least one heater or heating element disposedwithin at least one of the channels corresponding to each of the bricks.Each of the heating elements may be electrically connected to one ormore electrical power generation sources (also referred to as electricalenergy sources), either individually or collectively, and may beconfigured to receive electrical energy from the electrical powergeneration sources and generate thermal energy, such that temperature ofeach of the heating elements reaches to a temperature.

The application of electrical power to the heating element may becontrolled based on optimal heating conditions configured to reducethermal stresses in the bricks. Such electrical control may beimplemented by switches of various types, including electromechanicalcontactors and semiconductor devices including thyristor and transistortype devices including insulated-gate bipolar transistors (IGBTs). Thecontrol of electrical power to the heating element may be determined bya controller that takes into account values of currently available totalenergy from a VRE source or other parameters in determining a desiredrate of charging. The controller may operate a switch multiple times persecond in a control circuit whereby such operation of the switch enablesa heater to receive one of many average power levels. The controller mayoperate a plurality of such switches in a pattern such that an incomingamount of total power is distributed uniformly or nonuniformly across avarying number of heaters whose total power demand (if all operated atfull power concurrently) may exceed the incoming available power. Forexample, electrical energy may be controlled to keep the heating elementa fixed temperature above the surrounding bricks to reduce thermalstresses. As the brick temperature increases, more electrical energy maybe applied to the heating element to increase the temperature of theheating element to the maximum temperature achievable by the heatingelement. Therefore, heater elements at different vertical elevationswithin an assemblage of thermal storage blocks may be operated atdifferent temperatures, as higher blocks will typically have a greatertemperature.

Further, in some example implementations, the electrical power appliedto the heating element may be gradually ramped in during generation toprolong the life of the heating element. The means of this ramping mayinclude a controller commanding external power conversion devices,including solar inverters, to adjust their power delivery, and mayinclude a controller commanding semiconductor switching devicesincluding thyristors and IGBTs to rapidly switch in a time-varyingpattern. Additional optimizations of the charging of the system may beachieved by controlling the application of electrical power to theheating element.

In an example implementation, bricks may be made of thermally conductiveand absorbing materials having a composition and dimensions, such thatthermal energy emitted by the corresponding heating elements, uponreceiving the electrical energy, may heat each of the bricks and thecorresponding cells up to the first predefined temperatures. Further,the cells may be configured within the housing such that there is apredefined gap between adjacent cells, to facilitate the flow of fluidthrough the cells.

Brick Structure and Shape

The structure and shape of the bricks is configured to repeatedly heatand cool for the purpose of storing energy. Energy input is provided inthe form of electrical energy, which heats wires, filaments, rods, orother solid conductive materials to emit radiant thermal energy. Theenergy output is in the form of heat delivered in a circulating gasintroduced at one portion of the structure, and which leaves anotherportion of the structure at a higher temperature. The structure includesrefractory materials (e.g., bricks), which may be in the form of one ormore cast or extruded shapes, and so arranged as to have an alternatingsequence, along both vertical and horizontal axes. The structureincludes a plurality of open chambers and bricks, with the bricksincluding air passages having at least one dimension which is muchsmaller than the other two dimensions. The passages are open to thechambers at its top and bottom surfaces, and are internally exposed to aradiating surface heated by electrical resistance. In the chambers, heatis transferred by thermal radiation from relatively hotter surfaces torelatively cooler surfaces.

FIG. 36 shows views 36000 of brick and stack structure and shape, acutaway view 36001 and an isometric view 36003 of a chamber 36005 formedby the surfaces of adjacent bricks 36007 having channels 36009 formed asthe slots 36011. The resistive heater 36013 provides the heat energyconverted from electrical energy. One surface of the chamber 36003includes an surface heated to a higher temperature by electrical energy(shown as solid lines with arrows), and other surfaces of the chamberexposed to thermal radiation from all internal surfaces (shown as brokenlines with arrows).

In more detail, as shown in FIG. 37 , the structure 37000 comprised ofrefractory materials includes an inner chamber having a region directlyheated by electric power radiating heat. A region 37001 receives higherradiative flux from the electric power heating element and is at ahigher temperature, and is radiating thermal energy within the chamberthat is absorbed by lower temperature surfaces of the chamber 37002,37003, 37004 at different rates based on their angle and distance fromthe first radiant surface, and which consequently are heated todifferent temperatures by incoming radiation from region 37001. Thesecond surface 37002 is at a higher temperature than the third surface37003, which radiates thermal energy absorbed by the third surface37003, reducing the temperature difference between them. A fourthsurface 37004 is located farther from an electrical heating element andreceives incoming radiation emitted by the electrical heating element,the first surface region 37001, and surface regions 37002 and 37003, aswell as other surface areas.

The system as above, in which the brick materials whose respectivesurfaces form the walls of the chamber each have internal flow passages37005, which allow air to flow, having at least one dimension that issubstantially smaller than other dimensions, which causes the flowingair to have at least partly a turbulence pattern. Additionally, thesystem incorporates one or more regions below the first heated chamber,with air passages which enable flow upwards into the heated chamber, butso arranged as so block thermal radiation emitted by the heated chamber.

Electrical switches (not shown) control the operation of the electricalheaters under the command of a control system (not shown). Further,louvers and/or variable speed fans may control the rate of flow of airupwards within the air passages and chambers. FIG. 38 is a diagram 3300illustrating an example brick 3301 according to some implementations.The brick 3301 is formed in a zigzag shape, having an upper surfaceincluding a region containing openings 3303 (which are slots in thisexample) which extend vertically through the brick 3301. Additionally, aseating portion 3305 is provided, such as that bricks 3301 may thestacked on top of each other and seated in a manner such that they donot laterally shift with respect to one another. Further, side portions3307, 3313 in a longitudinal direction may be arranged with other bricksin a manner that creates chambers or cavities within the bricks. Theseradiative chambers may permit reradiation in various directions,including horizontal reradiation (e.g., charge the brick with radiationat 90 degrees to the vertical axis, such that radiation moves in thehorizontal plane).

The structure of bricks and stacks may promote the flow of energy in thehorizontal plane by giving radiation a free line of sight, or capabilityto radiatively move energy rapidly in the horizontal plane. Thisapproach may reduce or avoid hot spots. Simultaneously, energy isdischarged the vertical axis to the top of the stack. By allowingradiation to move freely in the horizontal plane but not substantiallyin the vertical axis, the thermocline may be maintained (and verticalreradiation from the point of discharge back down the stack isobstructed, such that the energy flows to the output in an intendedmanner).

The overall shape of the brick 3301 includes a first section thatextends longitudinally in a first direction, a second section that isoriented orthogonally to the first section and extends longitudinally ina second direction, and a third section that extends longitudinally inthe first direction. Thus, the brick 3301 has a zigzag appearance. Eachof the sections has the openings 3303 in a repeated pattern extendingalong the upper center surface, framed by the seating portion 3305 alongthe periphery. The seating portions of the second section and thirdsection are shown as 3309 and 3311, respectively. Additional recesses3315 and 3317 are provided at opposite ends of the first and thirdsections of the brick 3301.

In the illustrated implementation, fluid flow slots are elongated in onehorizontal direction. As shown, fluid flow slots may be oriented withtheir longer direction parallel to heater channels and perpendicular toradiation cavities at a given level.

FIG. 39 illustrates a schematic perspective view 3500 of a brick 3501according to another example implementation. While the brick 3301 shownin FIG. 38 has a common vertical profile across all of its sections, thebrick 3501 is assembled in a manner such that there are sections of thebrick at different vertical profiles. More specifically, the brick 3501includes a first portion 3501, a second portion 3503 and a third portion3507. These three portions 3501, 3503 and 3507 are connected at ajunction 3511. Recesses 3513 and 3515 are provided to house the heatingelement. As explained above, the openings 3509 are provided in each ofthe portions 3501, 3503 and 3507. A chamber formed by the bottom surfaceof the first portion 3501, and side surfaces of the second and thirdportions 3503 and 3507, respectively. Similar seating portions are alsoformed in the brick 3501 as explained above. Thus, the bricks 3501 maybe arranged in a stacked structure to form an assemblage, and multipleassemblage may be arranged to form a unit or cells, with a given TSUhaving one or more units or cells.

FIG. 40 illustrates a schematic perspective view 3100 of a brick 3101according to the above example implementation. The perspective view ispositioned to show the features of the brick 3101 from a sideperspective. As explained above, the brick 3101 includes sections 3103,3105 and 3107 that are connected to one another at a junction 3111.Slots 3109 and recesses 3113, 3115 are provided. Similar to the above aseating region is provided adjacent to the slots at the perimeter of theupper surfaces of the sections 3103, 3105 and 3107. The chamber formedby the sections 3103, 3105 and 3107 is directly behind section 3103,directly below section 3105, and directly to the left of section 3107 asillustrated. Other bricks 3101 may be positioned in a stacking orinterlocking manner with respect to the brick 3101, to form additionalsides of the chamber.

FIG. 41 illustrates an isometric view 3450 of interlocking bricksaccording to the example implementations. More specifically, bricks3401, 3403, 3405 and 3407 are arranged so that the seating regions ofthe bricks are arranged to interface with adjacent bricks. As explainedabove, this approach allows the bricks to be stacked in a manner thatreduces the risk of misalignment or undesirable movement after theinstallation. At 3409, a chamber formed by the interlocking bricks isshown. Thus, the bricks, once interlocked, form the chamber that issubstantially enclosed. In some implementations, an assemblage includesbricks oriented differently, e.g., with blocks rotated at differentangles, some blocks upside-down, etc.

Example Assemblage and TSU Structure

FIG. 42 illustrates an example refractory stack 3600 according to someimplementations. As shown in 3601, the bricks may be provided in aninterlocking manner, as explained above with respect to FIGS. 40 and 41. Further, the chamber or cavity is formed at 3603. Slots or openings3605 extend vertically through the bricks. As shown at 307, theresistive heating element is provided between some of the bricks. Asillustrated, the resistive heating element 3607 appears as a wire thatextends in a repeating curvilinear pattern horizontally with respect tothe fluid flow 3609 of the stack 3600. Other configurations of theresistive heating wire 3607 may be substituted for the configurationillustrated, so long as the resistive heating element 3607 receives theelectrical energy of the source as its input and generates heat energyduring a charging mode of the TSU.

In some implementations, the blocks are stacked adjacent in verticaltiers such that fluid cannot flow between tiers of blocks in ahorizontal direction, but flows only through vertical fluid pathwaysdefined by fluid slots and radiation chambers. This may facilitatecontrolled, even heating in various implementations.

FIG. 43 shows an isometric view 3700 of the stacking of the bricksaccording to an example implementation. As shown herein, bricks 3701 and3705 are stacked with respect to one another to form the radiativechambers 3709. A heating element may extend through a space 3707 (alsoreferred to as a channel) between some of the adjacent bricks.

FIG. 44 illustrates a side cutaway view 3800 of the stack of bricksaccording to the example implementation. For example, bricks 3801 arearranged in an interlocking manner with respect to one another. Someportions of the bricks have openings 3803, such as elongated slots thatextend vertically through those portions of the bricks. An opening 3805is provided between some of the bricks in a repeating pattern, bothhorizontally and vertically throughout the stack. The resistive heatingelement, depicted as 3807 is provided in the openings 3805. As the fluidflows vertically as shown at 3809, the fluid is heated. Although it isnot illustrated in this drawing, the radiative chambers formed by theinterlocking bricks, in conjunction with the openings 3805, provide forthe absorption of heat radiated from the heating elements 3807, andfurther allow for conduction of heat within a block in various directionand reradiation of the heat in various directions. In particular, theheat may be reradiated in a horizontal direction.

FIG. 45 illustrates an isometric view 3900 of the rows of stacked bricksaccording to the example implementations. More specifically, some of thebricks 3901, 3903 are interlocked with each other at a first level ofthe stack, and other portions of those same bricks at 3909 and 3911 areinter-locked with one another and a second layer of the stack. Adjacentbricks 3913 may interlock with some of the bricks in the adjacent row.Other bricks 3905 may not interlock with some of the bricks in theadjacent row, and may instead be separated by the space in which theheating element is positioned.

By forming an interlocking pattern between bricks, the stack may belaterally supported on the sides. For example, separate bricks at 3909and 3911 are spanned by a single brick at 3901 and 3903, to form theinterlocking pattern with the underlying bricks. As explained above, anupper surface of the brick has slots in a central portion and a lip atthe edge portion. The lip at the edge portion supports the load ofanother brick that is above the brick. Generally, lips or shelf portionson thermal storage blocks may interlock with other lips/shelves or withother block portions to prevent blocks from shifting laterally relativeto one another. For example, in an earthquake, the bricks may not movebecause they are surrounded with other bricks that are interlocked usingthe lip structure. The lateral support may result in a more stablestructure for the stack.

Additionally, the individual bricks may be formed at greater scale, withadditional walls, rows, chambers, vertical levels, slots and the likeused into a single block structure, such that multiple chambers areformed within the single block structure. The blocks may all be of thesame size, or they may be of different sizes. For example, and asexplained above, the height of bricks in the lower region of the stackmay be less than the height of bricks in the upper region of the stack.By having larger structures, fewer structures are required to form astack. Similarly, multiple bricks may be fused together prior tostacking, to have the same effect as a brick manufactured as a verylarge size and scale as a single block. In either case, a potentialbenefit of having fewer structures to form a stack is the ease ofassembly, e.g., in requiring the fitting of less pieces to one another.Further, the approach with larger blocks may also avoid a potentialdisadvantage of assembling more and smaller bricks, in that theinterlocked bricks that are stacked on top of each other may rub againstone another during the thermal expansion, thus causing additional wearand tear. The larger bricks have a smaller surface area in contact withother bricks, which may result in less wear and tear.

In some implementations, the slots that are adjacent to the heatingelements are parallel to the heating elements, while the slots that areabove the heating elements are orthogonal to the heating elements. Inthese implementations, the slots may be perpendicular to a wall fromwhich the energy will be radiatively received. As can be seen in thedrawing, a long row of slots is formed above and parallel to thedirection of the heating elements. The bricks have slots that areorthogonal to the long rows of slots, and those slots are spaced apartby the radiative chambers.

In some implementations, thermal storage blocks may be sized based onthermal conductivity. For example, in some implementations the thermalenergy should be radiated into the brick with a certain thermalconductivity, within a certain amount of time, given the thermal mass.If the brick size is too large, the amount of time required for theenergy to be radiated into the center portion of the brick may exceedthe available time, and the central portion of the brick will not heatup in time for the charge and discharge cycles. On the other hand, ifthe chamber is dimensioned below a certain width, while the temperaturemay become more homogeneous, the chamber may become too narrow, whichmay cause problems with flow or structural integrity.

The overall shape of the blocks may also be varied. While the examplesshown herein illustrate rectangular volumes with relatively flat wallsand interlocking structures with orthogonally position structures formedabove or below, the shape is not limited. For example, the bricks may beformed such that the overall shape is trapezoidal or oval instead ofrectangular. Further, the wall need not be flat, and may be curved,serpentine or some other profile. Also, as an alternative to havingslots in the bricks, the bricks may be configured to be stacked withsubstantially thinner elements to form gaps between the bricks, andalternating the bricks, to form the gaps as the equivalent of slots,such that the fluid passes between the bricks.

Additional Thermal Storage Block Examples

FIG. 46 is a diagram showing an isometric view of an assemblage ofthermal storage blocks. In the illustrated example, the storage blocksdefine channels (e.g., channel 4607) in which heater elements arepositioned. The channels may include horizontal slits for hanging heaterelements. As shown, the blocks define multiple radiation cavities 4601and multiple fluid flow slots 4603. The cavities and slots are arrangedsuch that a given vertical fluid flow pathway includes alternatingcavities and slots, with a cavity positioned above a slot that is inturn positioned above a cavity, and so on, until reaching the top of theassemblage. Thus, a given fluid pathway may include multiple cavitiesand multiple fluid flow slots, which may alternate. The volume definedby a given cavity is greater than the volume defined by a given fluidflow slot, in this example.

In the illustrated example, the blocks also include slots 4605positioned above the channels for the heater elements. Fluid flow mayalso occur via these slots, e.g., due to movement caused by a blower ordue to buoyancy of heated fluid. As shown, the heater channels 4607 arelocated adjacent to radiation cavities and orthogonal to the verticaldirection of fluid flow, which may promote horizontal radiation andenergy transfer. The heater elements may also heat the bricks viaconvection.

As shown, in some implementations the size of the radiation cavities isfairly large relative to the size of the block portions that bound thecavities. In some implementations, the area covered in a horizontalplane by a given radiation cavity is at least 40%, 60%, 70%, or 80% ofthe area of a surface of a portion of a thermal storage block thatbounds the radiation cavity (where the area of the surface of theportion of the thermal storage block includes the area of any slots inthe portion). The substantial size of the radiation cavities mayfacilitate even heating via radiated energy.

FIG. 47 is a diagram showing an exploded perspective view of the blocksof FIG. 46 . As shown, blocks may have different sizes in a given stack.The blocks may be formed such that multiple blocks define a giveradiation cavity or fluid flow slot. The relatively large size of theblocks in the illustrated implementation may reduce wear and tear due tofriction forces between blocks caused by slight blocks movements orexpansion/compression. Larger blocks may each include multiple radiationcavities and fluid flow slots and may also cover multiple cavities/slotson a lower level. Larger blocks may be manufactured as a whole (e.g.,using a correspondingly-sized mold) or in sections and fused together.As shown, a given block may include radiation cavities and fluid flowslots at multiple vertical elevations. Generally, a given block mayinclude multiple portions that each bound multiple radiation cavitiesand include one or more fluid flow slots.

FIG. 48 is a diagram showing a top-down view of the blocks of FIG. 46 ,according to some implementations. As shown, the fluid flow pathways areformed by corresponding sets of radiation chambers 4601 and fluid slots4603. This view also shows the slots 4605 positioned above and belowheater element channels.

FIG. 49 is a diagram showing a top-down view of one or more thermalstorage blocks, according to some implementations. In the illustratedexample, the block(s) include heater channels 49007, heater elements49009 positioned in the heater channels, heater slots 49005, radiationchambers 49001, and fluid flow slots 49003. In some implementations, therounded corners of the radiation chambers may facilitate relativelyuniform heating of the blocks.

Note that the block(s) of FIG. 49 -FIG. 51 are otherwise mostly similarto the blocks of FIG. 46 but with multiple fluid slots 49003 positionedabove a given radiation cavity 49001. In these implementations, thestream of fluid passes through the multiple fluid flow slots from acorresponding radiation cavity (and in many cases, from the multiplefluid flow slots into another corresponding radiation cavity of thefluid pathway). This may provide additional structural stability andthermal storage density. Further, the smaller slots may reduce laminarflow in the slots, which may improve energy transfer.

FIG. 50 is an isometric view of the block(s) of FIG. 49 and FIG. 51 is aside view of the block(s) of FIG. 49 .

Example Stacks and Thermal Storage Unit

FIG. 52 illustrates an isometric view 4000 of the stack 4001 of bricks(which may also be referred to as an assemblage) according to an exampleimplementation. More specifically, columns 4009 of the bricks areprovided. In this case, there are six columns. However, the number ofcolumns is not specifically limited, and more or less columns may beformed in a stack. Additionally, the stack has a lower portion 4003 andan upper portion 4005. Bricks at the lower portion 4003 may have asmaller height as compared with bricks at the upper portion 4005 of thestack 4001. Openings 4007 for the resistive heating elements are alsoshown for reference.

FIG. 53 illustrates a side view 4100 of an example system according tosome implementations. An outer structure 4101 may include a frame thatprovides seismic protection, as well as an outer surface of the TSUitself. The outer surface of the TSU and the frame need not be builtintegrally or even connected with one another, but may optionally havesuch an arrangement. Additionally, a foundation 4103 is provided at alower surface of the TSU. A steam generator 4105 is provided at anoutput of the TSU, as well as an air blower that is not illustrated.

The system may include multiple units 4107, 4109 that are individuallycontrolled for discharge and charge, as explained above. Each of theunits 4107, 4109 include stacks of bricks formed in columns 4119. Thebricks 4121 may include a passage or opening 4123, through which theresistive heating element may pass.

At the lower portion of the units 4107, 4109, the flow of incoming fluidmay be controlled by louvers 4111 and 4113, respectively. The louversmay be operated in conjunction with the hot fluid bypass, which isexplained above with respect to the overall system. As also explainedabove, each unit 4107, 4109 is controlled independently, such that thelouver 4111 is open while the louver 4113 is closed. Similarly, fluiddams or louvers may be provided at the upper portions, as depicted at4115 and 4117, respectively

FIG. 54 illustrates an isometric view 4200 of the system, with cutawaysshowing the system elements, according to the example implementations.More specifically, the structure 4201 may include the outer frame havingseismic protection features, either integrally or separate from theouter surface of the TSU. A foundation 4203 and the steam generator 4205are illustrated as well as the fluid blower 4223.

Each of the units 4207, 4209 may be separated by one or more bricksupport structures or walls having insulated properties. Thus, thecontroller may independently control the charge and discharge of each ofthe units 4207, 4209. Further, as explained above louvers 4211 and 4213are provided to control the flow of input pair to the units 4207, 4209.As shown at 4215, the heated fluid is channeled to the steam generator4205. For reference, each of the units 4207 includes multiple columns4221 of stacked bricks 4217, including heating elements in a space at4219.

FIG. 55 illustrates an isometric view 4300 of an outer structure 4301 ofthe TSU according to an example implementation. A duct or channel 4303is provided to output the hot fluid to the steam generator, which is notshown. The hot fluid is channeled from the stacks of bricks in the unitsby way of passages 4305.

FIG. 56 illustrates another perspective view 4400 of the thermal energystorage system according to the example implementations. It isunderstood that the stacks of bricks, units, dynamic insulation, andother structures and features described above are contained in the TSU4401. The output of the TSU 4401 provides hot fluid to output 4403. Thehot fluid is received at 4405 by a steam generator. However, additionalstructures may be provided such that the hot fluid is sent, eithersimultaneously or independently, directly to industrial application.Also shown is a water input 4407, which may pump water through theconduits of the steam generator 4405 based on water received as feedbackfrom industrial application, or water from an external source. The fluidblower 4409, which provides the cooled fluid that is the byproduct ofpassing through the steam generator, or reuse in the TSU 4401, ascirculated either by dynamic insulation or hot fluid bypass, asexplained above.

FIG. 57 illustrates an isometric view 4500 of the thermal energy storagesystem according to an example implementation. As explained above, thesystem may be framed with seismic protection features, either separateor integral with the outer structure 4501. Between the outer structure4501 and an insulation layer 4517, there is a fluid gap for dynamicinsulation as discussed in detail below, having the flow controlled bylouvers 4513 and 4515 at the entrance of the stacks. Further, a passage4503 receives the heated fluid from the stacks of bricks and the units,and passes the heated fluid to an output, and a duct 4505, whichprovides the heat to be used in industrial applications such as a steamgenerator or as direct airport other industrial process. The output maybe processed at 4507 at the steam generator. Additionally, at 4509,inputs of water and outputs of steam may be provided. The cooled fluidmay be recirculated to the TSU by way of the blower 4511.

Example System with Dynamic Insulation and Failsafe Venting Techniques

In some implementations, the system uses dynamic insulation toadvantageously improve insulation of a TSU, allow use of less expensiveinsulation materials, increase equipment life, or some combinationthereof. In some implementations, the system uses a stream of fluid thatwill eventually pass through one or more assemblages of thermal storageblocks to first facilitate passive insulation. In some implementations,the fluid is recycled, e.g., from a steam generator.

Further, the system may advantageously use failsafe venting to avoidoverheating in certain failure scenarios. The venting may also be usedfor temperature reduction to allow TSU maintenance. Disclosed dynamicinsulation and failsafe venting techniques may be implementedindependently (e.g., a system may use dynamic insulation but notfailsafe venting or vice versa). In some implementations, however, thetwo techniques operate in a synergistic manner. For example, thefailsafe venting may use the chimney effect to passively draw fluidthrough passageways through which fluid is normally directed by a blowerfor dynamic insulation.

FIG. 58 provides an isometric view of another example thermal storageunit, according to some implementations. In the illustrated example, thethermal storage unit 5800 includes an outside enclosure 5801 an externalvent closure 5803, side vents 5809, and components 5807. In someimplementations, various vents may open to cool the unit for maintenanceor to safely cool the unit in case of equipment failure. Examples ofpotential equipment failures include, without limitation: blowerfailures, power outages, water failures. Various elements utilized fordynamic insulation may also be used for passive cooling by the failsafemechanism.

In some implementations, at least a portion of the steam generator isincluded within the outer enclosure 5801 (as shown in FIG. 58 throughFIG. 62 and discussed in detail below). Other components 5807 locatedoutside the outer enclosure may include other steam generator componentssuch as a water pump, valves, an emergency pressure relief valve, etc.In some implementations, the portion of the steam generator in whichheated fluid from the thermal storage blocks interacts with water tubesis included in the outer enclosure. In some implementations, this mayadvantageously allow fluid leaks in certain locations to occur withinthe outer enclosure, which may mitigate effects of those leaks relativeto leaks to an exterior of the outer enclosure. Further, pressuredifferences within different parts of the unit may also mitigate effectsof fluid leaks. Components 5807 may further include other componentsthat are not part of the steam generator such as electrical components,cooling systems for electrical components, etc.

FIG. 59 provides an isometric view of the thermal storage unit withmultiple vents closures open, according to some implementations.Therefore, FIG. 59 may represent a maintenance or failsafe mode ofoperation. As shown, the thermal storage unit also includes an innerenclosure 5823 (shown in more detail in FIG. 60 ). The outer surface ofthe inner enclosure 5823 and the inner surface of the outer enclosuredefine a fluid passageway through which fluid may be conducted activelyfor dynamic cooling or passively for failsafe operation.

The inner enclosure 5823 includes two vents 5815 and 5817 which includecorresponding vent closures in some implementations (portions of ventdoor 5813, in this example). In some implementations, vents 5815 and5817 define respective passages between an interior of the innerenclosure 5823 and an exterior of the inner enclosure. When the externalvent closure 5803 is open, these two vents are exposed to the exteriorof the outer enclosure as well.

As shown, the vent 5815 may vent heated fluid from the thermal storageblocks conducted by duct 5819. The vent 5817 may allow entry of exteriorfluid into the fluid passageway and eventually into the bottoms of thethermal storage block assemblies via louvers 5811 (the vent closure 5809may remain closed in this situation). In some implementations, thebuoyancy of fluid heated by the blocks causes it to exit vent 5815 and achimney effect pulls external fluid into the outer enclosure via vent5817. This external fluid may then be directed through louvers 5811 dueto the chimney effect and facilitate cooling of the unit. Speakinggenerally, a first vent closure may open to output heated fluid and asecond vent closure may open to input external fluid for passive ventingoperation.

During passive cooling, the louvers 5811 may also receive external fluiddirectly, e.g., when vent closure 5809 is open. In this situation, bothvents 5815 and 5817 may output fluid from the inner and outerenclosures.

Vent door 5813 in the illustrated implementation, also closes an inputto the steam generator when the vents 5815 and 5817 are open. This mayprevent damage to steam generator components (such as water tubes) whenwater is cut off, the blower is not operating, or other failureconditions. The vent 5817 may communicate with one or more blowers whichmay allow fluid to passively move through the blowers even when they arenot operating. Speaking generally, one or more failsafe vent closure mayclose one or more passageways to cut off fluid heated by the thermalstorage blocks and reduce or avoid equipment damage.

When the vent door 5813 is closed (e.g., as shown in FIG. 60 ), it maydefine part of the fluid passageway used for dynamic insulation. Forexample, the fluid movement system may move fluid up along one wall ofthe inner enclosure, across an outer surface of the vent door 5813,across a roof of the inner enclosure, down one or more other sides ofthe inner enclosure, and into the thermal storage blocks (e.g., vialouvers 5811). Louvers 5811 may allow control of fluid flow intoassemblages of thermal storage blocks, including independent control ofseparately-insulated assemblages in some implementations

In the closed position, vent door 5813 may also define an input pathwayfor heated fluid to pass from the thermal storage blocks to the duct5819 and beneath the vent door 5813 into the steam generator to generatesteam. FIG. 61 shows a passageway 5829 that is open when the vent door5813 closes vents 5815 and 5817 for heated fluid to enter the steamgenerator.

In some implementations, one or more of vent door 5813, vent closure5803, and vent closure 5809 are configured to open in response to anonoperating condition of one or more system elements (e.g.,nonoperation of the fluid movement system, power failure, water failure,etc.). In some implementations, one or more vent closures or doors areheld in a closed position using electric power during normal operationand open automatically when electric power is lost or in response to asignal indicating to open.

As one example, the thermal storage unit may include a worm gear (notshown) configured to close a vent closure under electric power and anelectric clutch configured to hold the vent closure in position. In someimplementations, when the electric clutch is unpowered, the force ofgravity pulls the vent closure open. In some implementations, the unitincludes a counterweight configured to facilitate opening of one or morevent closures. In some implementations, the unit includes one or moreresilient members, for example springs, configured to push or pull avent closure open. In some implementations, one or more electricalswitches are configured to control opening or closing of one or morevent closures. Further, one or more vent closures may be opened manuallyor based on manual control input, e.g., for maintenance mode.

In some implementations, one or more vent closures are opened while afluid blower is operating, e.g., to rapidly cool the unit formaintenance.

FIG. 60 provides an isometric view of the thermal storage unit withmultiple vents closures closed and cutaways in the outer enclosure,according to some implementations. As shown, the enclosures formmultiple portions 5825 of a fluid passage between the inner enclosure5827 and the outer enclosure 5801. Fluid may move along these portionswhen driven by the fluid movement system (e.g., a blower 5821) fordynamic insulation or passively during failsafe operation.

FIG. 61 provides a more detailed perspective view of the primary ventclosure, according to some implementations. As shown passage 5829 leadsinto the steam generator and this input is closed off from the thermalstorage blocks when the vent door 5813 is open, but opens allow passageof external fluid into the outer enclosure (including into passage5825). FIG. 61 also shows an assemblage 5831 of thermal storage bricks.

FIG. 62 provides a still more detailed perspective view of a hinge forthe primary vent closure, according to some implementations. In theillustrated example, the vent door 5813 includes a hinge formed by acylinder 5833 and a slot in portion 5835 and is configured to rotateabout the hinge. In some implementations, the hinge is not centeredwhich may cause gravity to pull the door 5813 open when it is not heldshut. As shown, the door 5813 may include various surfaces configured toprovide a strong seal against one or more surfaces when open or closed.

As discussed above, dynamic insulation may be implemented in the TSU.The example system may also include passive failsafe safety features.When the system is switched off, thermal conduction might slowly heat upthe foundation without passive venting features. One or more vents maycreate a chimney effect by allowing external fluid into the system, andallowing the hot fluid within the system to be vented upward out of theunit. This may allow the system fluid out at a slow rate withoutrequiring a blower, due to the natural convective movement of fluidcaused by the buoyancy of hot fluid rising through the columns. Thisbuoyancy effect may pull cool fluid in and through the system as apassive safety measure, which opens the passage if power has beeninterrupted, and ensures that the system does not slowly overheat. Thisaspect of the example implementations may advantageously make the systemintrinsically safe and allow the system to be placed in locations thatmay not be otherwise permitted if the exterior surfaces were unsafe(e.g., too hot) to the touch.

This passive cooling may prevent the bricks from reaching temperatureshigh enough to melt steel reinforcing structures that provide seismicreinforcement and structural support for the bricks. This reinforcingstructure may be located within the unit but outside the dynamicinsulation passageway.

The buoyancy of fluid may enable an automated flow of the fluid throughat least one of the fluid pathways through thermal storage blocks fromthe bottom end of the cells to the upper end of the such that the fluidpassing through the bricks and/or heating elements of the cells absorbsthermal energy from the brick and/or heating elements, even when thefluid blowing units fail to operate in case of power or mechanicalfailure, thereby maintaining the temperature of the unit outer walls andsupports at or below their predefined temperatures. Such buoyancy-drivenflow may be obtained by one or more movable panels or other ports whichpassively open at an upper location and a lower location within thesystem upon such component failure or power failure.

The design of such ports and fluid flow conduits may improve theintrinsic passive safety of the unit, ensuring that critical elementssuch as structural supports and safety-related elements such as externalsurfaces do not exceed their design limits, without active equipment orthe requirement for supplied power. This configuration may allow thesystem to achieve a controlled, stable shutdown even in the event ofunexpected mechanical failure, sensor failure, or power loss to theblowers or any other control system failure. This configuration may alsofacilitate controlled cooling for maintenance, passively or inconjunction with one or more active blowers.

Brick Materials

In some implementations, thermal storage blocks are made of a refractorymaterial (e.g., castable) having high thermal conductivity andabsorption capability. The brick may be made of a predefined compositionof any or a combination of alumina, aggregates like magnetite orolivine, and binders. The material selection, sizing, and fraction ofaggregate in binder may be chosen to optimize strength, thermalconductivity, temperature range, specific heat, and/or cost. Forexample, materials of higher thermal conductivity reduce temperaturedifferences for given heat flux, and enable the use of fewer, largerbricks. Binder materials may be chosen which set during casting, or maybe chosen as materials which are thermally fired prior to use or whichchange composition once heated in use.

The bricks may be manufactured using a mold. More specifically, thematerial may be provided in a powder form that is mixed with water, toachieve a consistency based on the amount of added water relative to thevolume of power. The mixture is poured into a mold, and sets in the moldfor a period of time. The mold is removed, and the set bricks areformed. Alternatively, the bricks may be manufactured using a brickpress system or a brick extrusion system. Regardless of the method offabrication, the bricks may be formed in a manner that reduces oreliminates unintended voids within solid block areas.

FIG. 63 illustrates a composition 3200 of the brick 3201 according tothe example implementations. An aggregate 3203, 3209 is provided in abinder 3205. Additionally, heat conductivity elements 3213, phase changematerials 3211, and/or strengthening elements 3207 may also be included.

Brick elements may also include elements which improve the mechanicalstrength of the material, particularly in tension, such as needles orfibers or wires, and may include materials designed to change inphysical ways that absorb and release heat, such as reversiblethermochemical reactions or phase changes such as melting and freezing.These materials may be used selectively in some of the bricks, withdifferent bricks having different compositions.

The predefined composition of the thermally conductive materials and thepredefined dimension of the bricks being used, and the thermo-electricalattributes of the heating elements corresponding to each of the bricks,may be chosen such that each of the bricks corresponding to a cell maybe heated uniformly so that a substantially constant temperature profileis maintained along the length (or height) of each of the cells for apredetermined time. The foregoing example implementation may havebenefits and advantages, including slowing temperature ramp, as well asreducing the generation of hot and cold hot spots, mechanical stress,thermal stress, and cracking in the bricks. Further, the use of multiplebricks to form a single cell may facilitate larger channel surface areaand lower heat flux per unit area.

Bricks—Pretreatment

Thermal storage blocks and other components may also benefit frompre-treatment and conditioning. For example, a brick may be exposed toone or more thermal cycle with controlled heating and cooling rates,either prior to installation or within the storage system prior to beingput into service given that the initial cycles may have a larger impacton its mechanical properties than subsequent cycles.

Storage Unit Components/Integration

For the storage unit, shipping containers may be used, but are notlimited thereto. For example, the storage unit may be on the order of 6meters tall, housing the stacks of bricks. The containers includeelectronics and wires coupling the containers to the brick housingstructure that is protected to avoid damage due to external elementssuch as rain. The electronics may remain at ambient temperature,allowing for the use of standard, off-the shelf components, andreliability. A steam generator is coupled to the storage system, andcool fluid flows over, under and around the stacks.

The heater elements may be integrated inside and with the brick to heatthe storage media electrically during the charging period, such asduring the day (or at a time that may be determined by other factorssuch as availability of electricity at a relatively lower cost). Thestructure houses a stack of bricks with fluid passages that runsubstantially vertically through them; the hot fluid exits through aduct at the top of the stack and adjacent to pipes, so as to convertwater to steam. Cooler fluid may be recycled or may exit the back sideof the structure, for example.

The unit may have, at an end, a wall with holes and the end of wiresprotruding and the jumpers to connect the wires from one side to theother. At the other end of the unit, the containers may be configuredwith a distribution of bus bars provided for electrical distribution toprovide the power to the strings of wire heating elements. The bus barsare connected back to the controllers inside the containers.

The heating elements may be serviceable and replaceable, if needed, bysliding into and out of the openings passing through the building. Oldelements, or elements that otherwise require servicing or replacement,may be pushed or pulled out and replaced with a new one without the needto move other elements such as the bus bars. Thus, the unit may bedeenergized, the connections to the bus bar may be detached (e.g.,unscrewed) from the container side, and the heating elements may beremoved from the opposite side. New elements may be inserted from theopposite side and screwed into the bus bars from the container side, andthe unit re-energized. During such a maintenance period, insulation mayremain in place with the wire protruding through an insulating plug atthe end.

The space between the inner and outer roof may contain the relativelycooler return fluid, and the inner enclosure may contain the very hotfluid coming off (e.g., exiting) the top of the stacks. An internal ductis provided that facilitates transport of the fluid through a ductthrough the steam generator, where the fluid exits. A fan located at theoutput of the steam generator may be placed in cold fluid, in the cavitybetween the inner and outer rooms. This configuration allows the fan toavoid needing to have the metallurgy required for higher temperatureoperations, and increases its reliability.

The hot fluid duct feeding into the steam generator may become expensivedue to the high temperature of the fluid. It may also have a largepressure drop, since the fluid has expanded to multiple times the volumeit was when it was cool. Thus, the hot fluid duct must be significantlylarger than needed to handle the cool fluid. However, taking the fluidoff at one side of the inner roof may reduce the cost of the hightemperature duct for several reasons. For example, the quality ofinsulation that would otherwise be needed is not required, because anyheat which is leaking out of that high temperature duct will warm theinlet fluid. Further, the hot fluid duct is very short and direct. Aduct that needs to withstand such high temperatures is expensive,therefore limiting the length is beneficial. Further, the space betweenthe inner roof and the outer roof may also include a divider, and a fanmay be provided to control return fluid. On either side of this dividingwall, the return fluid is drawn back into the heating stack. Around theedges of the inner roof, a vertical duct is formed to allow the coolerfluid to descend to the bottom of the unit and return to the bottom ofthe brick stacks.

According to an example implementation, there is no other place (otherthan the duct connecting to the steam generator) where the outside ofthe unit experiences the full temperature of the system or the fulltemperature of the unit. This configuration may dramatically simplifythe insulation in other locations and may dramatically reduce the lossesand costs, at least because while there will be energy exiting thisstack of bricks and through this wall, the incoming fluid is slightlypreheated before it gets back to the stack of bricks.

The example implementation may be modified by optionally making itself-supporting and using a system of spacers to keep and maintain thespacing between the bricks. Conventionally, brick aspect ratio is chosenso that individual bricks do not topple in an earthquake, for example,by having a base width about 40%, e.g., 40%, of the height or greater.Spacers may be used to impart this stability on bricks that do not havethe desired aspect ratio, but interlocking smaller bricks together tomake a larger brick that has the desired stability. In this example, thespacers transfer forces from bricks above it and to the ones below andto the side through compression. This essentially makes the structureinto a pyramid, an inherently self-supporting and stable structure,without the need for excessive wall bracing. The spacers may be made ofa high temperature refractory or ceramic material and may also includefeatures to interface with wire hangers.

Thermocline and Radiation Chamber

The first temperature of the bricks and the heating elements may be kepthigher than the second temperature of the fluid for controlled dischargeof thermal energy from the first section into the second section. Forinstance, the heating elements may be heated at a first predefinedtemperature of 1200° C. so that the bricks or cells also gets heated upto 1200° C., and fluid at 250° C. may be supplied through from thebottom end of the cells and heating elements, so that the fluid, uponabsorbing thermal energy from the bricks and/or heating elements mayattain the second temperature of 800° C. Further, the heated fluid of800° C. may pass through the conduit such that the fluid inside theconduit may be converted into steam. Various structural aspects of thethermocline are provided below.

The bricks may be arranged to create a fluid passage between the bricks,in a repeating pattern. This results in the brick providing additionalsurface area for the heat in the brick to transfer to the fluid. Thebrick becomes a heat sink system. The fluid flow path is substantiallyvertically. Fluid comes into the bottom, goes up through these channels,gets heated as it goes up and escapes the top hot and goes into the roofarea.

The bricks may optionally have a consistent amount of thermal mass alongtheir length, to help maintain temperature uniformity and avoidsignificant narrowing that may cause hot spots. Optionally, the bricksmay include a chamfer at the top and bottom, so that if the bricks areslightly misaligned, the fluid pathways are not closed. The fluidpathways may be relatively narrow and it may be important that thebricks are not offset from each other, which would close the fluidpathways and reduce the fluid flow. Accordingly, chamfers and otherfeatures at the top in the bottom of the bricks may have the advantageof preventing misalignment.

The bricks of the example may be stacked, such as in a stack six or morebricks high. Some of the bricks have a corresponding heating elementthat winds through and is hung from a feature in the structure. Thebricks are spaced and designed such that they are self-supportingsystem.

From one slot for one set of heater wires to the next, a relativelysmall space, such as about 30 centimeters (for example, 30 centimeters),is required for the required performance because for the heating timeavailable during the day, the dimension is limited by the conductionrate. Larger dimensions may result in sections of the brick not beingefficiently used for thermal storage.

Optionally, the size of the fluid flow pathways may be adjusted to tunethe fluid flow velocity in different areas, to counteract thetemperature profile that already exists in the brick when it is heated.In other words, when the brick is heated, the side of the brick closestto the heater gets hottest and gets progressively cooler moving acrossthe brick. If the energy is extracted equally from the whole system, theoutput fluid temperature would be a gradient reflecting the bricktemperature gradient; hottest fluid near the wires and cooler fluidfurther from the heaters. Having larger pathways closer to the heaterelement may create less resistance to fluid flow, resulting in higherfluid velocity, and smaller channels further away from the heaterelement, which reduces fluid velocity in those regions, to obtain a morehomogeneous fluid temperature. As the fluid traveling at higher velocityis in the pathway for less time and is in contact with the brick forless time, that fluid exits the pathway cooler than fluid travelingslower through the same section. The side of the brick with the biggerchannels is hotter in the present example implementations; thus, size ofthese pathways may be tuned such that the fluid that comes out of thewide slots in the hottest part of the brick is nearly the sametemperature as the fluid that comes out of the narrower slots in thelower temperature part of the brick.

Thus, by tuning the geometry of the brick and fluid pathways, theperformance of the thermocline system may be improved and optimized tomatch the expected and desired charging and discharging characteristics.In addition to using differential fluid flow to even output temperature,by generally increasing or decreasing the overall fluid flow through thesystem, the temperature of the output fluid may be controlled.

According to some example implementations, the bricks are blocks thatare separate and effectively have voids. These voids, which might belarge voids, between the bricks in the stack create radiation chambers.In these example implementations, the energy may be transferred from thewire to the brick primarily by radiation energy transfer. When the wiresget hot, the radiation contacts the brick and comes into radiativebalance with a brick, where the brick is cooler than the wire trying tocome up to temperature, and radiation from the brick cools the wire.Energy from the wire is thus exposed to more surface area of brick ascompared with convective heating. The energy from this wire when itradiates down into this cavity energy penetrates into the cavity andbecomes exposed to more surface and mass of brick, instead of just thesurface right next to it, which gets a very high flux density and veryhigh energy density. According to this example implementation, somebricks may radiatively heat each other after being heated by the wire.Thus, the system may achieve both direct and indirect radiant heating ofbrick surface as part of the heat transfer. This design allows theheater element wire to be further spread out.

Without radiative cavities designed to heat large surface of brick inthis way, e.g., if conduction as the primary mechanism by which heat isbeing transferred, the design may be limited to a relatively smalldistance such as between 0.3 and 0.5 meters of space between wirecurtains in some implementations, when matched to heating profiles forsolar heating, as there is not enough time to heat the center of themass of the bricks. By using radiation cavities, the wire curtainspacing may be spread out to more than 0.5 m and still efficientlyutilize the entire mass of the brick. This allows for a reduction in thewire count. One benefit of this example implementation is that the totalwire count may be reduced, for example, from 3,400 wires to potentiallyapproximately 96 wires (for example, 96 wires) while transferring thesame amount of energy as was being transferred from the 3,400 wires.Further, this example implementation, may use wire having a diameter inthe range of 2.5 mm to 8 mm.

Design of Stack—Materials

During the course of normal operation of the thermal storage system,care may be taken to ensure that certain temperature ranges which maycause early failure are moved through quickly. For example, FeCrAl typealloys are known to embrittle if a significant amount of time is spentbetween 400-500° C. Different heating elements or bricks may have othersensitive temperature ranges where mechanical, thermal or physicalproperties are negatively affected. The control system may take thisinto consideration to avoid damaging the materials prematurely.

The thermal storage system may be designed in a way that some sectionsare made to handle higher temperatures. For example, a top section maycomprise higher temperature rated heating elements, such as onesconsisting of primarily SiC or MoSi2, and higher temperature ratedbrick, such as tabular alumina. Such a section could be heated, asrequired, to temperatures reaching 1500 C, 1600 C or higher. Thegeometry of bricks and wires may be different than those in anothersection of the thermal storage unit, to optimize performance, cost ormechanical stability. A second section of the storage, for example, inthe lower part of the stack, could have lower temperature rated heatingelements, such as metal heating elements in the FeCrAl class, and bricksthat are a different material type, selected for cost, performance andmechanical properties as more load is placed on the bricks at thebottom.

Flow Mixing Structures

Additionally, the flow channel through the brick stack may be modifiedto facilitate or promote the mixing of gas. These modifications mayreduce or eliminate hot spots and cool spots in the main stream. Forexample, the bricks may be structured (e.g., by fins or an arrangementof the slots) or assembled in a manner that directs the fluid to promoteswirling or mixing of the fluid in the chambers, to improve heattransfer of the convection. Such mixing may even out temperaturegradients, and have more even thermocline, and better performance, inaddition to the benefits of radiative and reradiative heating, asexplained above. This effect may be particularly advantageous at lowertemperatures, or the beginning of the charge or late in the charge.Further, the greatest thermal gradient stress, which typically occursmost acutely at the beginning and end of the charge, is reduced.

Additionally, cool bypass gas in the upper region of the stack may beblended by inducing swirl or turbulent flow, by a stationary auger orother feature at the top of the stack, with the gas discharged from thestacks, to obtain a more homogeneous temperature. For example, FIG. 64shows a side view 6401 and an isometric view 6403 of a stationary auger6405 at the top of the stacks, which may be used in combination withdiverters 6407, to channelize and blend the output fluid flow. As shownin greater detail in FIG. 65 , the diverters such as 651 at the top ofthe stacks divert the gas sideways instead of vertically, to create aswirl.

Heating Element

Traditional approaches may have problems and disadvantages associatedwith the heater for the thermal energy storage cells. For example, atraditional heater or heating element may experience problems anddisadvantages such as mechanically induced chemical failure, which isalso known as spalling. More specifically, scale growth may occur on theheater to a point where thermal stresses cause failure at an interfacebetween the scale and the substrate. A result of the scale growth isflaking and loss of aluminum, until the aluminum reservoir reaches acritical point. Additionally, intrinsic chemical failure may occur whenaluminum oxide breaks down, such that the aluminum migrates outward andthe oxygen migrates inward, until the aluminum reservoir reaches acritical point.

As a result of the foregoing related art problems and disadvantages, aphenomenon known as “breakaway oxidation” may occur, wherenon-protective Cr2O3 (chromium oxide) and FexOy (iron oxide) scalequickly, and eventually lead to bulk oxidation and failure of theheating element. Thus, the reliability and lifetime of the heatingelement is substantially shortened.

As explained above, resistive heating elements are provided in channelsthat are formed between stacks of bricks at repeated horizontal andvertical positions in the units. The resistive heating elements receiveelectrical energy from the source, which may be a renewable or anothersource of variable electricity. The resistive heating elements releasethe electrical energy as heat, which is radiated to the stacks of bricksas explained above.

The resistive heating elements may be in the form of wire, which may bein the form of coils or wires, ribbons, or rods which pass through thestack in channels oriented in a direction parallel to heat transferfluid flow or extend through the stack in channels transverse to heattransfer fluid flow.

According to an example implementation, coiled heating elements may bepositioned in grooves running across the top and bottom of one or morebricks that may be stacked together. The heating elements may pass fromone side of the unit to the other. With a jumper on one side and thecoming back through the other side, an electrical circuit may becompleted. The coils may be wired into series and parallel, to match thevoltages that are being worked with.

This diameter of wire may reduce the resistance of the long wire string.As wire may be purchased on a mass basis, and thinner wire hasadditional processing costs, which may result in a cost savings ofhundreds of thousands of dollars for one system, which is an addedbenefit. By using a thicker diameter wire, the overall life of the wiremay be significantly increased because there is no longercross-sectional wear from the heating or cooling of the wire, and thecorrosion of the wire is much less rapid due to the larger crosssection, even if the same corrosion rate. Further, increases of the wirediameter may further be feasible, potentially as high as 8 mm. Oneexample implementation has features that restrict the heating elementsfrom contacting the brick or each other, in case they undergodeformation. Such a feature could be a hook on multiple positions, forexample, at the top and bottom extremes.

FIG. 66(A)-(C) illustrate various configurations of the resistiveheating elements according to the example implementation. Resistanceheaters may be individually wired, wired in groups that connectresistance heaters in series, in parallel, or in a combination of seriesand parallel.

As shown at 4700 a, heaters 4701, 4702 extend through the refractorymaterial. Heaters are installed into conduits 4711 after assembly of therefractory material, or during assembly of the material. Protectivetubing 4707 may be used during installation and may be removedmechanically or melted or combusted by application of heat by theheater. Electric power connections 4704 are joined to heaters at points4703 with connections 4705 a that prevent excessive heat build-up atconnection points. Two or more heaters may be connected by successiveconnections 4705, 4706 before connection to power distribution 4704. Asshown in the drawing at 4700, two coil-type heaters 4701 are connectedby a connection 4706, followed by another two heaters in series alongpower connector 4704. Wire, rod, and ribbon-type heaters 4702 may besimilarly connected.

As shown in 4700 b, a refractory storage medium 4710, which may be thestacks of bricks, is provided with gaps or passages 4711 for theinclusion of the resistive heating elements. Further, the heaters may beof a ribbon type 4702, or a coil type 4701. Optionally, the heaters maybe enclosed in a conduit 4707 as explained above.

As shown at 4700 c, heaters 4701 with power connections 4704 arearranged with parallel links 4709 such that multiple heaters orseries-sets of heaters are connected in parallel to a single powerdistribution connection. Operation of the power connections may be atvoltages in the hundreds of volts to tens of thousands of volts.Voltages at or below 5 KV may be selected based on considerations suchas safety, costs, and reliability.

In some exemplary implementations, the heater(s) or heating elements maybe a resistance wire extending along the length of the channels of eachbrick, where each of the heating elements may have predefinedelectro-thermal attributes such as resistance, electrical conductivity,thermal conductivity, cross-section area, and the likes, such that eachof the heating elements may be heated up to the predefined temperaturesupon receiving electrical power from the electrical power sources.

Electrically, a loop may be formed by a heating wire that starts at anend of a first channel, passes through a jumper at the other end of thechannel, and returns via another channel. Adjacent stacks of bricks maybe phased apart (e.g., 3-phase, for adjacent stacks of bricks, such thatthe stacks forms a group, or cell). The group of stacks, or cell, may beresistance-matched so that the performance of the stacks is consistentwith respect to one another. The entire two of groups may form a zonethat is on a controller. Vertically, different zones (e.g., rows ofstacks) may be on different controllers, and may thus beresistance-matched at a different resistance from different verticallevels.

Further, the resistive heaters may be controlled such that the stacksare heated in an uneven manner. More specifically, the upper portions ofthe stacks may be preferentially heated. The controllers may control thevertical layers of the stacks separately, such that the heaters ondifferent layers of the stack may be turned on or turned off atdifferent times. For example, the controllers for the upper layers ofthe stacks may turn on the heating elements of the upper layers of thestack in advance of the controllers for the middle or lower layers ofthe stack turning on those heating elements. Further, this approachtakes into account the different in brick height and mass between thebricks at the lower layers, which have a lower height and mass, ascompared with the bricks at the upper layers, which have a greaterheight and mass. Thus, the upper brick layers will have a hottertemperature than the lower brick layers, and the thermocline ismaintained. The controller may set the temperature and the timing of theheating for the layers of the stack based on sensor feedback, or basedon system models, to determine the temperature of the layers, or acombination thereof.

The above example implementation of the brick design may be modified bystretching the above design and the heater element vertically. Thus,instead of being a round spiral, the heater may be a flat coil whichgoes into the brick and this allows every wire to have more surface areaand more exposure with the brick. This also allows the number of wiresin the system to be reduced, which may have a benefit of lowering thecost of the heater elements.

A wire irradiating to a larger surface may allow for more watts percentimeter of energy to be pushed in. The larger the surface area, themore brick is heated, which may have substantial implications on thetemperature of the wire, because the surface temperature of the brickthat the wire is exposed to sets a limit. A top wire temperature hasdirect implications on its lifetime, and the brick wall temperature thatthe wire is exposed to determines how much energy flux can be safelypushed through the wire. Thus, the example implementation involves abrick volume, exposed surface area, and wire temperature.

According to an example implementation, service is provided for theheater wire by forming a tall system wound up and down vertically andheating the sides of two separate bricks. The bricks are formed withfluid flow channels, and are substantially taller than the bricksdisclosed in the foregoing example implementations. Larger bricks withthe substantially same efficiency may allow fewer parts to bemanufactured, and for wires to be spaced out further. This exampleimplementation may have the added benefit of reducing cost of materialsand assembly. The bricks may be extruded, pressed or cast and are formedwith channels for the fluid to flow through. These channels, or slots,may provide a superior surface to volume ratio over holes or othershapes. The slots may or may not extend all the way at the edge closestto the heating element to concentrate the thermal mass close to theelements so that the energy transfers quickly.

As shown in FIG. 67 , the heating wire 6701 may be hanging from a rack6703 that is held in place by the hangers 6705 and a rod 6707. Spacers6709 are provided between the coils 6711 at the rod 6701, to preventsurfaces of the wire 6701 from touching. Optionally, spacers may beadded at the middle or bottom (not shown). Further, the cross-section,geometry, or materials may be adjusted.

For example, a twisted ribbon 6721 as shown in FIG. 68 , or a flatribbon 6731 as shown in FIG. 69 , may be provided. Similarly, thedifferent heaters may be used at different vertical levels of the stack.For example, the heaters near the inlet flow at a lower portion of thestack may require a different design than the heaters near the dischargeat the top of the stack, due to the different fluid flow conditions.

Coating Heating Elements

Other methods which may be employed to increase service life includesmaterial pre-treatment and conditioning. For example, FeCrAl typeheating elements are known to grow a protective, α-alumina scale on thesurface which greatly reduces the rate of oxidation of the bulkmaterial. However, at temperatures below 800-1000° C., a less protectiveform of alumina initially forms. To impart the protective effect of thedense α-alumina, the heater elements may be heated to a controlledtemperature and duration above 1000° C. prior to being placed intoservice. This may be performed pre-installation or inside the thermalstorage system post installation. The wires may also be pre-treated tochange the surface chemistry for longer life.

For example, it is known that the aluminum reserve in the bulk FeCrAlmaterial is an important limiting factor for oxidative failure. BecauseFeCrAl materials with aluminum fraction significantly higher than about5%, e.g., 5%, are not suitable for hot processing, a process which addsadditional aluminum may be beneficial. Such processes may include hotaluminizing, aluminum electro-plating, sol-gel processing and aluminumplating followed by anodizing. The surface treatment may also be made toincrease the emissivity of the surface such that the average temperatureof the heating element may be lower than without the treatment.

Replaceable Heating Elements

Individual heating elements may be configured to be removed and replacedwithout disassembly of the cell. For example, a broken or failed heatingelement may be pushed or pulled through the cell using a mechanicalpuller or pipe to remove and a replacement element placed in the cellusing a pipe or other specific tool. As may be understood by a person ofordinary skill in the art, the resistivity of heating elements maychange over time due to gradual physical effects from normal operationincluding wear, oxidation, and changing in metal crystal structure andalloying. In some example implementations, the replacement element maybe sized or constructed to produce a resistivity that mirrors aprojected resistivity of surrounding elements that may have degradedover during operation of the system.

For example, it may be anticipated that a portion of heating elementswill fail within a prescribed time, such as 3 years, of operation, andreplacement elements installed after three years may be designed with aresistivity that mirrors projected resistivity of the remaining originalelements that are still operation but have changed resistivity over theperiod of operation. Similarly, different resistivities may be chosenfor heating elements installed during later periods.

Control System

In various implementations the system includes a control unit or controlsystem operatively coupled to disclosed elements such as the electricalenergy sources, the heating elements, the air blowing units, the pumps,etc. In one implementation, the control unit is configured to enable theelectrical coupling of the heating elements with the electrical energysources. The control unit may switch the electrical connection of theheating elements between different electrical energy sources based onavailability and cost per kWh of the electrical energy sources. Duringlow load hours, the cost per kWh of non-renewable energy sources isgenerally relatively lower and sometimes negative. However, it may notbe feasible for the non-renewable energy sources to switch offelectrical power generation during these low load hours. Thus, duringthese low load hours, the control unit may electrically couple thesystem with an electrical energy source that is providing a lower costper kWh of energy. The control unit may further control the air blowingunits to enable controlled flow of fluid between any combination of oneor more insulated cells that include thermal storage block assembliesand the outside environment, and also control one or more pumps tofacilitate the controlled flow of fluid and steam through the conduit.

In an example implementation, system pumps and blowers are operable atvariable flow rates, such that energy production and steam generationmay be adjusted from a nominal full rate in steps or continuously downto a lower rate. Such minimum rate may be 10%, 20%, 30% of peak output,or another rate. The system controller may be configured to issuecommands to adjust the flow rate of the input liquid pump and the blowerso as to allow energy delivery at multiple rates automatically, based onmanual commands, or both.

In another example implementation, the control unit may be incommunication with a system associated with an electrical load or otherindustrial loads. The control unit may be configured to monitor thedemand for hot fluid, steam or electrical power at the load, as well theavailable energy being stored in the system, and may accordingly chargethe system by electrically connecting the heating elements to theelectrical energy sources. For instance, when the control unit findsthat the demand of the load is higher than the available energycurrently stored in the system, then the control unit may electricallycouple the heating elements of the system to the renewable ornon-renewable energy sources to meet the demand of the load.

If the available electrical energy being received by the electricalenergy sources is reduced, then during charging mode, the control unitmay electrically connect heating elements associated with apredetermined number of cells among all the cells of the housing, suchthat only the heating elements of a proper subset of cells may receivethe limited electrical energy and become heated, and the other heatingelements or cells remain electrically disconnected from the electricalenergy sources. Later, during discharging, the control unit may allowfluid to be passed through the heated cells to transfer the storedthermal energy to the conduit so the temperature of the fluid at theconduit remains at the delivery temperature, thereby reducing orpreventing any damages or failure in the steam production system, andpotentially maintaining continuous and controlled steam production.

The control system may generate a signal such as a command to activateone or more switching elements which in turn control source electricalenergy input to resistive heating elements. The control system maydirectly or indirectly command the operation of active switches whichselectively interrupt current flow so as to deliver a chosen averagepower. Such switching patterns may be carried out by thyristor-typeswitches which are continuously on or selectively commanded to switch soas to deliver a lower power by selectively conducting during chosenpatterns of half-cycles.

A plurality of such switches may be chosen to operate in a pattern suchthat during each half-cycle of an AC current flow, the average load isconstant. One such pattern would have the same or similar number ofswitches turned on during each half-cycle, even though any given switchmight be turned on only once during a sequence of multiple cycles. Otherswitching patterns may be carried out by insulated-gate bipolartransistor (IGBT)-type switches which operate at frequencies higher than120 Hz and which selectively conduct or block current in a pattern toprovide continuous conduction or partial power whether incoming power isin the form of AC or DC.

The control system may determine switching decisions based in part onvarious parameters, such as the design of the heating element, includingits resistance per unit length, its material surface area, its materialof construction including its performance with temperature(temperature-related effects may include metal recrystallization and/ordealloying, oxidation, spalling, creep, thermal expansion, and wear) thetemperature and size of the surface area surrounding the heatingelement, local temperatures along the entire heating element length(including support points or points of contact with solid media andpoints of electrical connection with other conductors), etc., or somecombination thereof. Overtemperature at points of connection may bereduced or prevented by arranging regions of lower electrical resistanceproximate to such connections, e.g., by winding multiple strands of wiretogether, changing conductor cross-section, making such connectionsoutside high-temperature regions of the storage unit, or providing localheat-sink/cooling elements at such points.

FIG. 70 illustrates the resistive heating element 7000 according to anexample implementation. The resistive heating element 7001 is positionedin a conduit 7003 having an outer wall having a surface temperature asindicated by 7007. The surface temperature 7007 depends on the bulktemperature distribution of the brick, its thermal conductivity, and theradiative heat flux. Switching decisions may be based in part on thedesign of the heating element 7009, including its resistance per unitlength, its material surface area, its material of constructionincluding its performance with temperature (temperature-related effectsincluding metal recrystallization and/or dealloying, oxidation,spalling, creep, thermal expansion, and wear) the temperature and sizeof the surface area surrounding the heating element 7007, 7009, andlocal temperatures along the entire heating element length, includingsupport points or points of contact with solid media 7011, 7013, 7015.The surface temperature of the heating element 7001, 7017 may depend onthe wattage per unit surface area of heating element, the ambient airtemperature around the element, whether or not air is flowing in theconduit in the region defined by 7003 and 7005, and the surfacetemperature of the enclosing material 7007. The surface temperature at7007 depends on the bulk temperature distribution of the brick, itsthermal conductivity, and the radiative heat flux; radiative heattransfer dominates. Since this is proportional to the difference of thetemperatures in degrees Kelvin to the fourth power, as the refractorymaterial approaches the maximum operating temperature of the heater, thepower flowing through the heater should approach zero.

In one implementation, the surface temperature of the heating elementdepends on the wattage per unit surface area of heating element, theambient air temperature around the element, whether or not air isflowing in the conduit, and the surface temperature of the enclosingmaterial. The surface temperature depends on the bulk temperaturedistribution of the brick, its thermal conductivity, and the radiativeheat flux. Radiative heat transfer may dominate in disclosedimplementations. Because radiation transfer is proportional to thedifference of the temperatures in degrees Kelvin to the fourth power, asthe refractory material approaches the maximum operating temperature ofthe heater, the power flowing through the heater should approach zero.

In some implementations the control system algorithms include models ofthe thermal storage unit. These models approximately simulate thetemperature at various points within the storage unit, as well asinstantaneous and forecast temperatures based on heater power input.Accordingly, heater life is advantageously preserved, by incorporatingweather and seasonal inputs into the controller, including the use offorecasting.

The models may adapt to changes in the configuration of the storageunit, including the presence of missing or failed heaters or heatercontrollers, the presence of blocked heat transfer channels, thepresence of scale formation in the steam generation section, or otheroperating/maintenance matters.

In one implementation, the control system confirms and comparessimulation models to select measurements of temperatures, flows, andpower levels at various points within the system. The control system mayconsider the models in control calculations governing power to theheating elements. For example, wall temperatures may be a limitingfactor in the current input power allowable for a given heater, withlimits calculated based on peak refractory temperature and peak wiretemperature. A constant-wattage (constant-Q heat flux) charging may notbe feasible without the heater temperature significantly exceeding therefractory temperature.

The control system responding to such constraints may command chargingwattage (e.g., Q heat flux) patterns in time during charging, whereinitial low-rate heating establishes heat conduction patterns, chargingis raised to high rates for part of the charging time, and charging ratedrops as material temperature rises, such that the final top temperatureis approached asymptotically at slow rates, without exceeding top heatertemperatures.

Heat transfer fluid may be flowing in the adjacent fluid conduits duringcharging, allowing charge plus discharge operation concurrently. In someexample implementations, heat transfer fluid may be flowing in theconduit that carries the heater element. The resistance per unit lengthof the heating element may vary, and/or the heat production per unitlength may vary, so that (for example) a conduit which has heat transferfluid flowing axially along the heater may require less heat near thefluid outlet than near the fluid inlet.

Advantages

In addition to those advantages described above in Section I, theexample implementations relating to thermal blocks and assemblages mayalso afford various advantages relative to traditional approaches. Forexample, traditional approaches commonly suffer from uneven heatdistribution, wear and tear due to the heating and cooling cycles of thebricks, and safety and maintenance issues. The implementations withinthis disclosure, however, attempt to mitigate various such problems byapplying radiative heating (including horizontal radial radiation withinthe radiation chambers) in combination with fluid flow pathways, toproduce a distribution of heat that is more uniform than that achievedby traditional heating techniques. As a result, problems anddisadvantages associated the art may be overcome, such as inefficientpower storage, degradation, damage and breakdown of various elements(e.g., the heating element, the bricks, the enclosures, etc.), unsafehotspots, etc.

Disclosed dynamic insulation techniques may advantageously improveinsulation efficiency, reduce insulation costs, or both relative totraditional techniques. Further, disclosed passive cooling techniquesmay improve the safety of the thermal storage system. Various disclosedtechniques may reduce maintenance complexity relative to traditionaltechniques.

The storage media blocks may be arranged in an assemblage that allowsrelative movement to accommodate expansion and contraction by individualelements. Also, the array is arranged such that cycles of thermalexpansion align the elements of the array to preserve the integrity ofthe array structure, the integrity of the heating element conduits, andthe integrity of the heat transfer gas conduits.

Further, because the heat is more evenly stored, waste of heat is alsoreduced or avoided. Additionally, the example implementations may haveanother benefit, in that it may be easier to maintain and replace theheater modules, heating elements, and bricks. Further, the exampleimplementations have increased efficiency. For example, the brick andstack configurations disclosed herein may produce an increase in the ΔTof the bulk material over the course of charging and discharging toallow the bricks to store more megawatt hours per kilogram of material,as compared with current designs.

III. DC/DC Conversion

In many power transfer systems, alternating current (AC) is employed totransfer power from a generating source to a load. In such systems,passive equipment and transformers need to be energized for the systemto work, resulting in the circulation of reactive energy. Additionally,the transfer of AC over distances can result in losses due to impedanceof transmission lines coupled between the generating source and theload. In some cases, the power generated may be intermittent. Forexample, when the generating source is photovoltaic cells, the powerbeing transferred is based on the illumination of the photovoltaiccells, which can vary over the course of the day. As the power drops,the efficiency of the AC transfer system can be further degraded.

To improve the efficiency of such power transfers, direct current (DC)transfer can be employed which use multiple input DC voltages togenerate a higher voltage for transmission. In some cases, the transmitvoltage can be decomposed into multiple smaller voltages at the load endof the transfer system. As described below, the losses associated withconverting DC sources to AC for transfer can be eliminated due to lowerinductive and eddy current losses. Additionally, ohmic resistive loadscan be lower further improving efficiency.

A block diagram of such a thermal storage system the employs DC powertransfer is depicted in FIG. 71 . As illustrated power transfer system3100 includes generator circuits 3101A-C, converter circuit 3101,converter circuit 3102, and thermal storage unit 3104.

Generator circuits 3103A-C are configured to generate DC voltages3107A-C, respectively. In various implementations, generator circuits3103A-C may employ renewable energy sources such as solar or wind. DCvoltages 3107A-C may, in some implementations, be time-varying voltages.For example, in some cases, the respectively levels of DC voltages3107A-C may be based on variation in illumination of photovoltaicpanels. Although only three generator circuits are depicted in theimplementation of FIG. 71 , in other implementations, any suitablenumber of generator circuits may be employed.

As described below, converter circuit 3101 includes multiplesub-converter circuits, each including a first input circuit and a firstoutput circuit. The first input circuit is configured to receive one ofDC voltages 3107A-C. The first output circuit is galvanically isolatedfrom the first input circuit and is configured to generate acorresponding one of DC voltages 3109A. Converter circuit 3101 isconfigured to combine DC voltages 3109A to generate transmit voltage3108.

As described below, converter circuit 3102 also includes multiplesub-converter circuits, each including a second input circuit and asecond output circuit. The second input circuit is configured toreceive, via transmission line 3106, a portion of transmit voltage 3108.The second output circuit is galvanically isolated from the second inputcircuit and configured to generate a corresponding one of DC voltages3110 derived from the portion of transmit voltage 3108 received by thesecond input circuit. Converter circuit 3102 is configured to combine DCvoltages 3110 on output bus 3105. It is noted that, in someimplementations, DC voltages 3110 may be coupled, in parallel, ontooutput bus 3105.

Thermal storage unit 3104 includes heating element 3111 coupled tooutput bus 3105. In various implementations, heating element 3111 ispositioned to heat thermal storage medium 3112 using power received viaoutput bus 3105. As described elsewhere in the specification, thermalstorage unit 3104 may be implemented using a variety of differentthermal storage mediums.

In some cases, voltages from multiple energy sources can be combinedinto a transmit voltage that may be used directly by a load. A blockdiagram of an implementation of power transmission system for arenewable energy source system is depicted in FIG. 72 . As illustrated,power transmission system 3200 includes converter circuit 3101,renewable energy sources 3202A-C, and thermal storage unit 3104.Converter circuit 3101 includes sub-converter circuits 3203A-C.

Renewable energy sources 3202A-C are configured to generate DC voltages3205A-C, respectively. In various implementations, renewable energysources 3202A-C may be implemented using photovoltaic cells, windturbines, or any other suitable renewable energy source. DC voltages3205A-C may, in some implementations, vary in time due to theintermittent nature of illumination of the photovoltaic cells, theabsence of wind, and the like. Although only three renewable energysources are depicted in the implementation of FIG. 72 , in otherimplementations, any suitable number of renewable energy sources may beemployed.

Sub-converter circuits 3203A-C are configured to receive DC voltages3205A-C, respectively. In various implementations, sub-convertercircuits 3203A-C are configured to generate output voltages 3206A-Cusing corresponding ones of DC voltages 3205A-C. As described below,sub-converter circuits 3201A-C include respective input circuits andoutput circuits that are galvanically isolated by correspondingtransformers.

Sub-converter circuits 3203A-C are coupled in series to combine outputvoltages 3206A-C to generate transmit voltage 3108. In variousimplementations, transmit voltage 3108 is a sum of output voltages3206A-C. By coupling sub-converter circuits 3203A-C in series, a voltagelarger than any of one of DC voltages 3205A-C can be generated to aid inthe transmission of power to thermal storage unit 3104. Moreover,coupling sub-converter circuits 3203A-C in series eliminate the need todetect failures in any of renewable energy sources 3202A-C. If any oneof renewable energy sources 3202A-C stops generating its correspondingone of DC voltages 3205A-C, the corresponding one of sub-convertercircuits 3203A-C generates a zero output voltage which still allows thegeneration of transmit voltage 3207 by adding the output voltages of theremaining ones of sub-converter circuits 3203A-C.

Although converter circuit 3201 is depicted as including only threesub-converter circuits, in other embodiments, any suitable number ofsub-converter circuits may be employed. In some cases, the number ofsub-converter circuits included in converter circuit 3101 may correspondto a number of renewable energy sources. Alternatively, multiplerenewable energy sources may be wired together and a number ofsub-converter circuits may be based on a desired magnitude of transmitvoltage 3108.

Thermal storage unit 3104 includes heating element 3108 configured toheat thermal storage medium 3109 using transmit voltage 3107. In variousembodiments, thermal storage unit 3104 may be coupled to the output ofup-converter circuit 3101 using a high-voltage DC cable capable ofhandling the current drawn by thermal storage unit 3104 at the value oftransmit voltage 3107. As described elsewhere in the specification,thermal storage unit 3104 may be implemented using a heating elementwhich can be used to heat a variety of different thermal storagemediums.

Turning to FIG. 73 , a block diagram of an embodiment of a powerreceiver system for a transmitted direct current voltage is depicted. Asillustrated, power receiver system 3300 includes converter circuit 3102,and load circuit 3306.

Converter circuit 3102 includes sub-converter circuits 3302A-C that arecoupled in series across transmit voltage 3108. It is noted that whilesub-converter circuits 3302A-C are depicted as being across transmitvoltage 3108, in other embodiments, sub-converter circuits 3302A-C maybe coupled across any suitable DC voltage. By coupling sub-convertercircuits 3302A-C in series, transmit voltage 3108 is divided intovoltage portions 3303A-C, with corresponding inputs of each ofsub-converter circuits 3302A-C being exposed to only a portion oftransmit voltage 3108. In the illustrated embodiment, since there arethree sub-converter circuits, each of voltage portions 3303A-C is athird of the value of transmit voltage 3108. Using series-coupledsub-converter circuits may, in various embodiments, allow for the use oflower voltage components in sub-converter circuits 3302A-C, therebysaving cost and circuit complexity.

Sub-converter circuits 3302A-C are configured to receive correspondingones of voltage portions 3303A-C. For example, sub-converter circuit3302A is configured to receive voltage portion 3303A, whilesub-converter circuit 3302B is configured to receive voltage portion3303B. Sub-converter circuits 3302A-C are further configured togenerate, using corresponding ones of voltage portions 3303A-C,corresponding ones of load voltages 3304A-C. As with sub-convertercircuits 3203A-C, sub-converter circuits 3302A-C include input andoutput circuits that are galvanically isolated from each other. Use ofsuch isolation may prevent possible damaging currents flowing directlyfrom cables carrying transmit voltage 3108 to load circuit 3306.

Although converter circuit 3102 is depicted as including only threesub-converter circuits, in other embodiments, any suitable number ofconverter circuits may be employed. In some cases, the number ofsub-converter circuits included in converter circuit 3102 may be basedon a value of transmit voltage 3108 and desired values of load voltages3304A-C. For example, if smaller values are desired for load voltages3304A-C, additional sub-converter circuits may be employed to splittransmit voltage 3108 into a larger number of smaller portions.

Load circuit 3306 is coupled to output bus 3105 and is configured toperform a function or operation using a voltage level of output bus3105. It is noted that load circuit 3306 may be any suitable circuit orunit that employs a DC voltage to perform a function or operation. Invarious embodiments, load circuit 3306 may be part of a thermal storageunit (e.g., thermal storage unit 3104) while, in other cases, loadcircuit 3306 may be part of an electric vehicle charging system, orother battery charging system. For example, load circuit 3306 mayinclude charging circuit 3207 configured to charge battery 3208 usingpower received via output bus 3105.

Turning to FIG. 74 a block diagram of an embodiment of a sub-convertercircuit is depicted. As illustrated, sub-converter circuit 3400 includesDC converter circuit 3401, transformer 3402, output circuit 3419,control circuit 3405, and control circuit 3406. Output circuit 3419includes rectifier circuit 3403 and output voltage generator circuit3404. In various embodiments, sub-converter circuit 3400 may correspondto any of sub-converter circuits 3203A-C or sub-converter circuits3302A-C.

DC converter circuit 3401 is configured to receive DC input voltage3409. In various embodiments, DC input voltage 3409 may correspond toany of DC voltages 3205A-C, or voltage portions 3303A-C. DC convertercircuit 3401 is further configured to generate current 3410 in primarycoil 3407 included in transformer 3402 using DC input voltage 3409 andbased on control signals 3414. In some embodiments, current 3410 is analternating current, and to generate current 3410, DC converter circuit3401 may be further configured to switch the polarity of DC inputvoltage 3409 relative to the terminals of primary coil 3407 in order tochange the direction of current 3410 through primary coil 3407. Invarious embodiments, a frequency of such switching may be based on atleast one of control signals 3414.

In various embodiments, DC converter circuit 3401 is magneticallycoupled to output circuit 3419 by transformer 3402. Since the DCconverter circuit 3401 is coupled magnetically to output circuit 3419,no current can flow between DC converter circuit 3401 and output circuit3419 thereby galvanically isolating the two circuits.

As current 3410 flows in primary coil 3407, a time-varying magneticfield is generated by primary coil 3407. The time-varying magnetic fieldinduces current 3411 in secondary coil 3408 of transformer 3402. It isnoted that due to the time-varying nature of the magnetic field, current3411 may also be an alternating current. To enhance the inductivecoupling between primary coil 3407 and secondary coil 3408, therespective windings of primary coil 3407 and secondary coil 3408 may bewound around a common core of ferrous material.

To provide additional granularity for the level of transmit voltage3108, transformer 3402 may be used to change the value of DC outputvoltage 3413 relative to DC input voltage 3409. By adjusting the numberof turns (or “windings”) of primary coil 3407 relative to the number ofturns of secondary coil 3408, the magnitude of current 3411 can beadjusted, either up or down, relative to the magnitude of current 3410.For example, if the number of turns of secondary coil 3408 is greaterthan the number of turns of primary coil 3407, then the magnitude ofcurrent 3411 will be greater than the magnitude of current 3410.Different values of current 3411 can result in different values of DCoutput voltage 3413.

Since current 3411 is an alternating current, it must be converted to aDC voltage (or “rectified”) before it can be used by output voltagegenerator circuit 3404. Rectifier circuit 3403 is configured to generateinternal supply voltage 3412 using current 3411 flowing in secondarycoil 3408. In various embodiments, rectifier circuit 3403 may beimplemented with multiple diodes to maintain a charge on a loadcapacitor in order to generate internal supply voltage 3412.

Output voltage generator circuit 3404 is configured to generate DCoutput voltage 3413 using internal supply voltage 3412 and based oncontrol signals 3415. In various embodiments, DC output voltage 3413 maycorrespond to any of output voltages 3206A-C or load voltages 3304A-C.Output voltage generator circuit 3404 may, in some embodiments, includeinductive choke 3418, which may be used to couple one instance ofconverter circuit 3400 to another instance of converter circuit 3400 asdepicted in the embodiment of FIG. 72 . In various embodiments, outputvoltage generator circuit 3404 may be implemented using a buck convertercircuit or any other suitable circuit.

Control circuit 3405 is configured to generate control signals 3414.Such signals may include timing and enable signals for DC convertercircuit 3401. In various embodiments, control circuit 3405 may beconfigured to generate control signals 3414 using external communicationsignals 3417 and communication signals 3416. In various embodiments,external communication signals 3417 may be sent to and received fromanother sub-converter circuit or a master control circuit included in apower transfer system. It is noted that the transmission of externalcommunication signals 3417 and communication signals 3416 may beperformed using optical circuits to provide electrical isolation betweencontrol circuit 3405, control circuit 3406, and any external controlcircuits. In various embodiments, control circuit 3405 may beimplemented using a processor configured to execute software or programinstructions, a microcontroller, other suitable state machine.

Control circuit 3406 is configured to generate control signals 3415,which may include timing and enable signals for output voltage generatorcircuit 3404. In various embodiments, control circuit 3406 may beconfigured to generate control signals 3415 using communication signals3416 received from control circuit 3405. Control circuit 3406 may alsobe configured to send information regarding the operation and status ofoutput voltage generator circuit 3404 to control circuit 3405 viacommunication signals 3416. In various embodiments, control circuit 3406may be implemented using a processor configured to execute software orprogram instructions, a microcontroller, other suitable state machine.

Turning to FIG. 75 , a flow diagram depicting an embodiment of a methodfor operating a DC power transfer system is illustrated. The method,which may be applied to various DC power transfer systems including DCpower transfer system 3400, begins in block 3501.

The method includes receiving, by an input circuit of a given convertercircuit of a first plurality of converter circuits, a DC input voltagefrom a renewable energy source (block 3502). In some embodiments, themethod further includes generating, by a plurality of photovoltaicpanels, the DC input voltage.

The method also includes generating, by an output circuit of the givenconverter circuit that is galvanically isolated from the input circuit,a second plurality of DC output voltage based on the DC input voltage(block 3503). In various embodiments, generating the DC output voltageincludes inducing, by the given converter circuit using the DC inputvoltage, a first current in a primary coil of a transformer included inthe given converter circuit. In such cases, the method also includesgenerating, by the given converter circuit using a second current in asecondary coil of the transformer, the DC output voltage. In variousembodiments, the second current in the secondary coil is based on thefirst current in the primary coil of the transformer.

In some embodiments, the method may further include inducing the secondcurrent in the secondary coil based on the first current, a first numberof turns on the primary coil, and a second number of turns on thesecondary coil. The method may, in various embodiments, also includerectifying, by the given converter circuit, the second current togenerate an internal supply voltage. In such cases, the method mayfurther include generating, by the given converter circuit, the DCoutput voltage using the internal supply voltage.

The method further includes respective DC output voltages from the firstplurality of converter circuits to produce a transmit voltage (block3504). In some embodiments, the method includes adding the respective DCvoltages to produce the transmit voltage. In various embodiments,coupling the first plurality of converter circuits includes coupling afirst output of a first converter circuit to a particular node using afirst inductive choke, and coupling a second output of a secondconverter circuit to the particular node using a second inductive choke.

The method also includes heating a thermal storage medium by a heatingelement using the transmit voltage (block 3505). In some embodiments,the method also includes receiving, by a second plurality of convertercircuits coupled in series, the transmit voltage. The method may furtherincludes generating, by the second plurality of converter circuits usingcorresponding portions of the transmit voltage, a plurality of DC outputvoltages, and combining the plurality of DC output voltages on a commonpower bus. The method concludes in block 3506.

Vehicle Charging Applications

The above described DC/DC converter can be used for a DC vehicle fastcharging application. This example circuit illustrates how it ispossible for a standard 500 MAC cable to transport 2 MW. Existingcharging stations are connected to AC grid and either have their ownsubstation or are connected to a bigger substation at 5060 Hz and lowvoltage. To pull 2 MW, a very high current is required (4,000 amps)exceeding the limits of the grid capacity.

By being able to transfer power using DC allows 1-2 MW power transfer ata much lower current allowing battery charging in 10-15 minutes to 80%,similar to a gas station stop. The DC/DC converter shown above may allowthis high-speed DC charging. This structure uses multiple PV arraymicrogrids as input, for example, and the DC/DC converters shown canprovide high power and economical charging stations. Additionally, thecharging station may also include on-site storage of the PV generatedpower using standard cabling.

Thus, relatively small conductors at substantial voltage can be used topower a set of charging ports that can operate independently or inparallel.

Power Transportation Applications

If a PV panel connected with an inverter that is converting to AC andusing a transformer to step up to a higher voltage to transfer it over adistance, then at the destination such as a charging station, battery orstorage system, there is a transformer or some sort of rectifier. Whensuch a system is running at peak solar capacity, the losses of theinverters and the transformers and the energizing losses of that ACsystem the eddy current and the inductive losses add to just under 90percent efficiency. However, when the system is running at low power,the losses remain similar and the net efficiency drops substantially.

Conversely, when doing a DC based system using the DC/DC convertersdescribed herein, losses are significantly lower since inductive or eddycurrent losses are not present in DC and ohmic resistive loads arelower. Thus, the efficiency increases slightly at low loads.

Thus, these chained DC/DC converter systems can have applications infields such as power transportation, vehicle charging, customerapplications, solar fields connected to lithium battery systems amongothers, including a thermal storage system. This may significantlyreduce ohmic losses in solar fields because wiring would be running athigher voltage and may reduce ohmic and AC losses between solar fieldsand batteries or solar field batteries and charging stations. Manymicrogrids will have these same issues because reliability of thatmicrogrid and its efficiency change if its frequency is decoupled fromthe main grid.

The DC/DC converter designs and implementations create the opportunityto run a fully DC microgrid, particularly at high voltage. For example,a 25 kV DC microgrid around a site and solar facilities can meanbatteries can run at ultra-high efficiency. Some loads may be directlyDC connected and some loads may be connected via inverters designed forpower point loads. There may also be gateway inverters or rectifiersthat gateway to an AC grid but the microgrid is not phase locked to thegrid would mean that grid instabilities can't take it down. The value of25 kV is just provided as an example, and other values may be usedinstead.

With AC systems, there is a need to energize all the passive equipmentand transformers thus circulating a lot of reactive energy, andtransferring AC over distances can additionally incur losses with lineimpedances and power bouncing.

DC power sharing over medium distances can be done very effectivelyusing this DC/DC converter design, may enable more effective energystorage, more efficient energy transportation, using medium voltage DCfor example up to 50 miles.

Further, the DC/DC converter design eliminates the transformers andallows building that voltage by scaling them in series, which can beessentially lossless. This is made possible by each cluster being fullygalvanically isolated, with two separate controllers (master/slavecontrol). Further, there may also be top level-level power management toprevent excessive voltage rise in the main conductor if power demand onthe load drops.

In addition to the controller in each device (DC/DC converter) there mayalso be one overall controller that will be in charge of thoseconversions and conversion stages to set limits to those devices and howthey can behave (limit power; limit current; limit voltage) to setboundary conditions.

Thus, voltage sharing can be based on the idea of power sharing becauseif sharing power is started, then logically the voltage will be sharedacross those devices and the system will experience the same voltagedrop on the input, same voltage drops on the output.

The high voltage DC/DC conversion allows for very high efficiencyconnection of solar fields with suitable distance to loads such as aheated brick energy storage unit that can be coupled to electrolyzersand used for electric vehicle charging. Further, the system could haveintegrated hydrogen production and electric power generation fromhydrogen and further have integration of lithium-ion batteries. Thesystem can also be coupled to drive desalination to produce a completelyoff-grid facility or military base that is self-powering for itsdomestic loads, its heat loads and its vehicles.

IV. Industrial Applications

The above-described thermal energy storage system provides a stableoutput of heat from electrical energy that may be supplied from arenewable source. The stable output of heat may be provided to variousindustrial applications, to address art problems, as explained below.

The ultrahigh temperatures capable of a radiatively heated thermalenergy system 100 allow for application in a wide range of industrialprocesses. In particular, for processes that require ultrahightemperatures, for example in glass production and metallurgicalapplications, such a high temperature thermal energy storage systempowered by renewable energy provides the possibility of operatingentirely or in large part from renewable energy around the clock,providing a path toward zero carbon processes.

A. Material Activation

1. Problems to be Solved

Cement production is one of the largest sources of global carbonemissions, responsible for as much as 8% of global CO₂ emissions. Thecarbon emission from cement production, however, has been growing morequickly than fossil fuel production. The unmet need to decarbonize themanufacture of cement is thus becoming even more of a criticalrequirement to achieve reductions in global CO₂ emissions in order tostabilize Earth's climate.

Cement is typically made from limestone and clay (or shale). These rawmaterials are mined, then crushed to a fine powder. The blended rawmaterial (“raw feed” or “kiln feed” or “meal”) is heated in a rotarykiln where the blended raw material reaches a temperature of about 1400°C. to 1500° C., e.g., 1400° C. to 1500° C. In its simplest form, therotary kiln is a tube that may be, for example, 200 meters long and 6meters in diameter, with a long flame at one end. The raw feed entersthe kiln at the cool end and gradually passes down to the hot end, thenfalls out of the kiln and cools down. In the initial stages at lowertemperature (e.g., 70-600° C., and more specifically, 70-350° C.), freewater evaporates from the raw feed, clay-like minerals and dolomitedecompose into their constituent oxides, producing calcium carbonate,magnesium oxide and carbon dioxide.

Over intermediate temperatures (650-1050° C.), some calcium carbonatereacts with silica to form belite (Ca₂SiO₄) and carbon dioxide.Remaining calcium carbonate decomposes to calcium oxide and CO₂. At thehottest regions (1300-1450° C.) of the kiln, partial melting takes placeand belite reacts with calcium oxide to form alite (Ca3.SiO4). Therotary kiln is used in more than 95% of modern world cement production.

The material exiting the kiln, referred to as “clinker”, is typicallycomposed of rounded nodules. The hot clinker falls into a cooler, whichmay be designed to recover some of its heat, and cools to a temperaturesuitable for storage (or is directly passed to the cement mill where itis ground to a fine powder). Gypsum or other materials may be groundtogether with the clinker to form the final cement product.

The hottest end of the rotary kiln heated by a combination of recoveredheat from the hot clinker and burning of fuels is at the exit of theclinker. The heated gas travels in a direction counter to the clinkerprocess. The exhaust gas exits where raw feed enters the rotary kiln.

A majority of cement production uses a separate precalciner to increaseproduction and efficiency for a given cement kiln. The precalciner is asuspension preheater which allows some of the energy required for theprocess to be burned at its base. The precalciner allows more thermalprocessing to be accomplished efficiently in the preheater, greatlyincreasing throughput for a given sized rotary kiln tube.

Depending on the system design, a precalciner can output feed that is40-95% calcined, at high end, leaving the primary role of the rotarykiln for sintering. The input gas to the precalciner may be preheated bythe hot air recovered from cooling clinkers, in addition to the fuelburned. The hot gases exiting the top of the precalciner are often usedfor drying raw materials. This process, however, tends to beintermittent, thereby wasting heat when the rawmill is stopped.

In some cement production systems, a bypass between the kiln inlet andthe precalciner may be installed to extract the dust containingmaterials potentially damaging to equipment and to final productquality. The collected material, referred to as the cement kiln bypassdust (CBPD), can be approximately 2%, e.g., 2%, of the total clinkerproduction by weight and consists primarily of calcium oxide, a keycomponent of clinker, as well as salts such as KCl and othercontaminants. CBPD is usually landfilled at a cost.

CBPD mainly includes already decarbonized calcium oxide. A recent studyhas shown that temperatures of approximately 900-1200° C., e.g.,900-1200° C., can transform CBPD into valuable clinker components suchas belite, mayenite, alite and ferrite at lower temperatures than in therotary kiln (assisted by other components in CBPD while vaporizing andremoving contaminants such as KCl) leaving behind a cementitious productfree from a majority of the undesired contaminants which are initiallypresent.

In a traditional cement plant, fuel and oxygen are fired to provide heatinto the clinker kiln. This fuel may be in the form of solid media suchas refuse or coal (or may be natural gas) introduced along withcombustion air into the kiln. At the outlet of the kiln, a stream of hotcombustion gases provides a portion of the heat used to preheat the mealand then calcine the meal; the balance of that heat may be supplied bycombustion of a fuel and/or heat recovered from hot clinker cooling. Theprocess of calcination consumes about 20-75%, e.g., 20-75%, of thermalenergy from fuel depending on precalciner design and operation.

The term “calcination” broadly refers to a process in which a solidchemical compound is heated to a controlled, high temperature in acontrolled environment in the presence of little to no oxygen to removeimpurities and/or to incur thermal decomposition to a desired product.The term calcination has traditionally referred to a process fordecomposing limestone (or calcium carbonate) into quicklime (calciumoxide) and carbon dioxide. This reaction is widely used in industrygiven that limestone is an abundant mineral and that quicklime is usedin the production of cement, mortar, plaster, paint, steel, paper andpulp as well as in the treatment of water and flue gases.

Other calcination processes include the dehydroxylation (i.e., removalof crystalline water) of gypsum used in producing building materials andother products and the dehydroxylation of alumina used in producingaluminum metal and other products. Another calcination process is thedehydroxylation of clay minerals, which may be used for the activationof clay for use as a supplementary cementitious material (SCM) in acement mixture, such as alongside Portland cement. Clay mineralactivation differs from its limestone counterpart in that the reactionreleases water (—OH groups) instead of CO₂.

Different calcination reactions require different operating conditions(e.g., temperature, environment compositions, etc.) to expose mineralsto heat and drive calcination. Over time, different designs have beendeveloped, including shaft furnaces, rotary kilns, multiple hearthfurnaces, and fluidized bed reactors. Many associated processes havealso been developed including internal radiant heating via fuelcombustion within a kiln or reactor, internal convective heating via hotgas flow within a kiln or reactor, or external heating of a kiln orreactor. These traditional modes are referred to as soak-calcinationprocesses, given that the material takes several minutes to hours in thereaction chamber to become fully activated.

Flash calcination is another approach, which is more rapid than the soakprocess, and takes place in a reactor that uses gases at velocities andtemperatures creating gas-particle interactions including entrainmentand suspension, so as to drive effective heat transfer and encouragechemical reactions. Systems using this principle commonly introduce agas that has been heated via combustion of a fuel (including directexhausted combustion products) and/or a gas that may be heated fromcooling the products of calcination (or recovered from other heatsources, at the bottom of a reaction chamber in an up-flowconfiguration). The gas temperature may commonly range from 600° C. to1100° C. In one implementation, raw clay material to be processed isfinely divided and is fed into a chamber above the hot gas injectionpoint. Upward flowing hot gases interact with raw material and maysuspend the raw material through the chamber where the particles arequickly heated by the flowing gases.

Additional sources of heat may be incorporated within (or without) thechamber, including fuel combustion devices or additional hot gasintroduction ports, to maintain a desired temperature profile or ambientgas composition. As the material exits the chamber, it has been heatedto the desired state of calcination (or activation). The gas compositionwithin the chamber may be selected to perform a function of controllingthe quality of the product. For example, oxygen may be excluded or theremay be a reducing atmosphere zone for quality control of the product.The material to be processed may contain iron that will become oxidizedin non-reducing environments and cause the product to change color whichmay not be desired. This atmosphere reduction zone may be enforced viainjection of reducing gases or supplied via supplemental burners inwhich any oxygen in the air is reduced via injected fuel. After heatingand calcination, the material is then rapidly cooled, often by air incooling cyclones or another form of air quench. Water can also be usedas a cooling fluid in certain processes. The product is cooled to 100°C. to 200° C.

Some attempts have been made to analyze clay calcination in gassuspension heaters in order to determine the effect of operatingconditions. In one example, a kaolinite particle feed was added above aburner and passed through the chamber with and without supplementalburners along the channel. Convection was the dominant form of heattransfer in the process where an ideal gas supply temperature was about900° C., e.g., 900° C., without supplemental burners.

In these approaches, internal resistive heaters cannot be used toreplace a burner in the calciner. The technical reason is that it isextremely hard to heat the large gas volume needed for gas suspensionpurely via resistive heaters, as the space and cost required would betoo large. Additionally, the resistive heaters may experiencedegradation due to the particulate matter present in a calcinationprocess.

2. Calciner Heated by Electric Power from Thermal Energy Storage

The present disclosure describes example implementations that involvethe replacement of fired fuel and/or hot gas generators with a novelhigh-temperature thermal energy storage (TES) system. Exampleimplementations cover multiple embodiments of a material activationsystem with different degrees of integration into material activationprocesses, which may be used to produce quicklime in someimplementations or other activated materials such as activated clay oralumina. Example implementations relate to a novel TES system'sintegration with a material heating system using any of a variety ofcalciner/kiln configurations. In some implementations, the integrationcould be with an existing plant where the TES system and all processmodifications are retrofitted to an existing material activation system.In other implementations, a new material activation system is built inwhich the material heating system is designed around the thermal energystorage system.

In one implementation, a thermal storage system may be used as areplacement for existing hot gas generators in material activationprocesses. Accordingly, one or more thermal energy storage arrays mayprovide hot gas as the primary heat transfer fluid for convective heattransfer demands of the material heating system. These demands mayinclude the drying, preheating, cooling, or calciner heating and may befilled via direct tie-in to a thermal storage unit. Gas of anycomposition may be either recirculated through the TES system after useor fanned in from ambient air, to be used at higher temperatures in theprocess.

In various implementations, the material activation system includes theabove-disclosed thermal energy storage system transferring heat intoair, into CO₂, into CO₂ with a small air fraction, into gases which varyin composition with time (e.g., a dominant gas with a second gas such asair or O₂ being present at a different concentration during somefraction of operating hours), and/or into gases arising from aninterconnected industrial process, such as mineral calcination. In afurther implementation, a small amount of hydrogen or other reducing gasmay be included with the carbon dioxide. Example implementations mayalso include provisions for tolerating, separating, and/or removingentrained particulate matter in a structure such that periodic cleaningmaintains long-term performance of the TES system.

In some implementations, carbon dioxide is used as the heat transferfluid to deliver heat into the material activation process and is thencombined with additional carbon dioxide released by calcination.Accordingly, no carbon dioxide separation processes are required (otherthan condensing any water which results from the combustion of fuel). Inanother example implementation, thermal energy storage systems employedin the process can heat multiple different gases or gas mixtures for usein the material activation system.

Example implementations as disclosed herein can be considered withregard to two subclasses. In the first subclass, a TES system directlysupplies heat in the form of a heated fluid (such as air, CO₂, gaseouscombustion products, or a combination of multiple gases), replacing acombustion-based hot gas generator for some or all of its typicalapplications in a material activation process. These applicationsinclude, but are not limited to, drying raw material (such as limestone,clay, bauxite, or raw meal), aiding in reactor start up and cool down(getting a reactor to auto ignition temperature (600° C. to 1500° C.)),and preheating raw material (such as limestone, clay, bauxite, raw meal,or a mixture) to desired reactor operating conditions (400 to °1000°C.). Implementations in this first subclass may apply tocombustion-based material heating systems such as fuel-firedcalciner/kilns, where all auxiliary heat needs other than the burners inthe calciner/kiln are provided by thermal energy stored in the TESsystem.

The second subclass is a more highly integrated process in which the TESsystem is used to supply thermal energy/heat in the material activationprocess and combustion may be used in moderation (if at all) to providesuitable atmosphere control for the desired reaction. Exampleimplementations include different process configurations of the TESsystem integration. In various implementations, one or more hightemperature TES units supply heat directly or indirectly to the calcineror kiln reactors as well as dryers and pre-heaters.

In implementations that employ direct heat transfer, the fluid used asthe heat transfer medium in the TES system is being supplied directly tothe raw material in the calciner and then recirculated back to the TESsystem after coming into direct contact with the raw material. Inimplementations that employ indirect heat transfer, the fluid used inthe TES system does not come into direct, physical contact with thematerial in the material heating system. Rather, in someimplementations, the fluid in the TES system is used to transfer thermalenergy via a heat exchanger into a secondary fluid that comes intocontact the material. In other implementations, the fluid used in theTES system may indirectly heat the raw material without the presence ofa secondary fluid by heating the walls of the calciner or kiln reactorsystem, with the heated walls transferring heat to the raw material onthe other side of the wall via conduction and radiation. This “indirect”heating mode of thermal storage operation can also be used inapplications other than calcination or kiln reactors, including but notlimited to biomass drying or food processing. The secondary fluid may bein the liquid state in some implementations.

There is also a combination of direct and indirect heating modes for theTES system fluid where the higher temperature TES system fluid exchangesheat indirectly with a secondary fluid (with a gas-to-gas heatexchanger, for example) and additionally raises the temperature of thesecondary fluid stream via direct injection by a bypass configured toinject a portion of the higher temperature fluid from the TES systeminto the secondary fluid provided to the material heating system. Thiscan be useful for atmosphere control within the material heating system(and within the TES system as well in some implementations). Thesecondary fluid mixed with some of the TES fluid is then exposeddirectly to the raw material of the material activation process tosupply heat. After supplying heat, this secondary fluid may be treatedto remove undesired components that were added to the stream via contactwith the raw material such as water, undesired emissions (SOx, NOx, CO,etc. . . . ), and particulate matter. Some or all of this treatedsecondary fluid may be used to fill other auxiliary heat demands such asdrying or preheating or treating or cooling demands (oftentimes, rawmaterial must be cooled after reactions in the calciner/kiln reactorzones). Some or all of the secondary fluid may be returned to the heatexchanger where the stream can be reheated.

In some implementations, a small portion of the heat may also besupplied via supplementary combustion in the material activationprocess. This may raise the temperature of the gaseous heat transferstream depending on the specific operating conditions associated withthe combustion. Generally, the fuel would be combusted ‘fuel rich’meaning that there is more fuel than stoichiometric oxygen in thereaction. The primary reason for this fuel rich combustion is atmospherecontrol as clay, for example, requires slightly reducing systems to notoxidize the iron in the clay and hence prohibit ‘color change’. Forexample, the amount of oxygen may be reduced, and the iron in the claymay be reduced. The TES system may, however, require slightly oxidizingconditions for nominal operation. The supplementary combustion wouldremove the small amount of oxygen and create color reducing conditionsfor the clay. The final product to be output is activated clay, which isused instead of clinker to make cement.

There are several relevant calcination processes that are covered by thematerial activation system described herein. Different processes oftendemand different operating conditions (temperature, pressure, residencetime, gaseous composition in the calciner, etc. . . . ) although variouscomponents of the material activation system may be shared amongstdifferent processes.

FIG. 76 illustrates an example implementation of a material activationsystem 76010 described herein. As shown, material activation system76010 includes a TES system 76020, a material heating system 76030, anda recirculation system 76040. TES system 76020 includes one or morethermal energy storages 76022. Material heating system 76030 includes apre-heater/precalciner 76032, kiln/calciner 76034, atmosphere reductionsystem 76036, and a cooling system 76038. In other implementations,material activation system 76010 may include more (or fewer) componentsthan shown; components may also be arranged differently.

As discussed in greater detail in other sections, TES system 76020 isconfigured to store thermal energy derived from an energy source. Insome implementations, this energy source is a renewable energy source(e.g., wind, solar, hydroelectric, etc.) or some other form of variableenergy source. Thermal energy storages 76022 within TES system 76020 mayinclude heating elements configured to heat a storage medium usingelectricity from the energy source. These heating elements may includeany of the various examples described herein including, for example,thermal resistors, ceramic resistors, etc. The storage medium mayinclude any of various examples described herein such as brick, stone,etc.

To facilitate extraction of thermal energy from the heated storagemedium, blowers may be used that are configured to heat a non-combustivefluid (e.g., carbon dioxide, nitrogen, air, or others discussedpreviously) by circulating the non-combustive fluid through the heatedstorage medium. As noted above, the use of non-combustive fuel stands incontrast to prior combustion-based systems that rely on a combustivefluid (e.g., natural gas, propane, methane, etc.) to provide energy. Invarious implementations, TES system 76020 is configured to provide thiscirculated non-combustive fluid to the material heating system tofacilitate activating a raw material. In some implementations, TESsystem 76020 is configured to provide the circulated non-combustivefluid to the material heating system at a temperature within a range offrom 600° C. to 1100° C.; however, the fluid may have a differenttemperature in other implementations.

Material heating system 76030, in general, is configured to applythermal energy to a raw material to produce an activated material.Techniques described with respect to the material heating system may beemployed with respect to any of various material activation processes.As discussed above, in some implementations, material heating system76030 is a calcination system configured to perform a calcinationprocess that removes carbon dioxide from a supply of calcium carbonateto produce calcium oxide. In other implementations, material heatingsystem 76030 is configured to perform a dehydroxylation process (i.e.,use of heat energy to remove molecularly bound water) that removeshydroxide from clay minerals to produce activated clay. In otherimplementations discussed below with FIG. 83 , material heating system76030 is configured to implement a single stage of the Bayer processthat includes a calcination step which transforms bauxite to producealuminum oxide as the activated material.

In various implementations, material heating system 76030 is configuredto receive thermal energy derived from the non-combustive fluid providedby TES system 76020. As previously discussed, the provided fluid may beused in a direct heating implementation in which material heating system76030 brings the provided fluid into contact with the material. Theprovided fluid may alternatively be used in an indirect heatingimplementation in which a heat exchanger is configured to receive thecirculated non-combustive fluid from TES system 76020, transfer heatfrom the circulated non-combustive fluid into a second fluid, andprovide the heated second fluid to material heating system 76030 forapplying the thermal energy to the raw material. In a mixed fluidimplementation, material activation system 76010 may further include abypass configured to inject a portion of the circulated non-combustivefluid received from TES system 76020 into the second fluid provided tomaterial heating system 76030. In some implementations in which TESsystem 76020 is unable to supply enough thermal energy for materialheating system 76030, material activation system 76010 may furtherinclude a burner (or some other combustion based energy source)configured to supply combustion energy to the material heating system inaddition to the thermal energy supplied by the TES system.

Pre-heater 76032 is configured to apply thermal energy derived from thecirculated non-combustive fluid to heat the raw material to a firsttemperature before providing the heated raw material to the kiln forheating to a second temperature. In some implementations in which theBayer process is performed, pre-heater 76032 is configured to implementa first stage of the Bayer process that includes heating the bauxite toa temperature within a range from 300° C. to 480° C. and at a firstpressure within a range of 6 bar to 8 bar. In the illustratedimplementation, the thermal energy applied by pre-heater 76032 isreceived from TES system 76020; however, in other implementations, someor all of this thermal energy may be obtained from an exhaust fluidoutput by kiln 76034.

Kiln 76034, in various implementations, is the primary componentresponsible for applying thermal energy to a raw material to produce anactivated material. Kiln 76034 may be implemented using any suitabletechniques such as flash calcination, rotary kiln, or others discussedabove. For example, in some implementations, kiln 76034 is configured toapply the received thermal energy by injecting the raw material via afirst inlet of the kiln and injecting, via a second inlet underneath thefirst inlet, the heated non-combustive fluid in an up-flow configurationthat suspends the raw material within the kiln in order to moreefficiently heat the material. In one implementation in which the Bayerprocess is performed, kiln 76034 is configured to implement a secondstage of the Bayer process that includes elevating a temperature of thebauxite within a temperature range from 750° C. to 950° C. and a secondpressure lower than the first pressure.

Atmosphere reduction system 76036 is configured to reduce an amount ofoxygen in contact with the activated material produced in kiln 76034before the material is cooled. In implementations that produce activatedclay, the removal of oxygen may prevent the activated clay from becomingdiscolored due to oxidation of any iron present in the clay. In oneimplementation, atmosphere reduction system 76036 includes a burner thatcombusts a rich fuel mixture to produce carbon monoxide to absorb anyexcess oxygen. In some implementations, atmosphere reduction system76036 may not be used as either the activated material may not reactwith oxygen or the fluid in contact with the material may alreadyinclude a low oxygen content, such as in a direct heating implementationin which carbon dioxide is used as the non-combustive fluid.

Cooling system 76038 is configured to receive the activated material ofthe material heating system and reduce a temperature of the activatedmaterial. Cooling system 76038 may employ any suitable techniques suchas using cooling cyclones or other techniques noted above. In someimplementations, the exhaust fluids are collected from cooling system76038 for recirculation by recirculation system 76040.

Recirculation system 76040, in general, is configured to recover thermalenergy that has not been consumed by the material activation process. Inthe illustrated implementation, this recovery includes recirculatingexhaust fluid output from material heating system 76030 to TES system76020. In implementations that produce carbon dioxide as a biproduct ofthe material activation process, recirculation system 76040 mayrecirculate produced carbon dioxide to TES system 76020 for use as thenon-combustive fluid. In various implementations, recirculation system76040 includes a filter configured to remove particulate from theexhaust fluid prior to the exhaust fluid being provided to the TESsystem.

As noted above and discussed in more detail below, in someimplementations excess thermal energy may be used for various otherpurposes. For example, material activation system 76010 may include asteam cycle system that includes a heat exchanger configured to producesteam from thermal energy recovered from material heating system 76030and a steam turbine configured to generate electricity from the producedsteam.

FIG. 77 illustrates another implementation 76050 of—a materialactivation system using electrically heated thermal energy storagesR1-R4. The overall process uses carbon dioxide as the principal heattransfer medium through the kiln/calciner and precalciner. No air,nitrogen, or excess oxygen is introduced into the kiln, and as a result,the CO₂ that is evolved by the calcination reaction is mixed with CO₂that was supplied as the process heat carrier and any CO₂ produced byfuel combustion, so that the gas stream at point D, the exit of thepreheater calciner unit, is nearly pure CO₂, potentially with some waterif fuel is combusted. This CO₂ stream in part or whole, is optionallyused to dry raw materials, increasing its moisture content and is partlycooled and compressed-/-pumped away, and partly recirculated to thethermal energy storages R1 and R2 to carry further heat into theprocess. Each thermal energy storages R1 and R2 accepts a CO₂ stream ata lower temperature and heats that CO₂ stream to a very high exittemperature by passing it through a series of conduits in solid materialwhich has been heated by electrical energy (e.g., the “storage mediacore”). Thus, a closed carbon dioxide cycle heat transfer is provided.

By choosing appropriate materials for heating elements and heat storagemedia, the heat transfer gas may be selected among a wide range ofcompositions, including but not limited to any of, or any mixture of,air, N2, O2, CO₂, H2O, and other gases or gas mixtures. Optionally, aminimum level of oxygen may be included, depending on the composition ofthe resistive heating element. In addition to carbon dioxide asexplained above, in combination with a fraction of hydrogen gas or otherreducing gas, nitrogen may also be used. A benefit of using nitrogen isthat it is inert and the primary gas present in atmospheric air. Certaingases interact with metallic heaters in such a manner as to limit theiroperating temperatures. Heating materials which form protective oxidescales are compatible with the continuous or intermittent presence ofoxygen. Other heaters, including conductive ceramics and encapsulatedheaters, enable higher operating temperatures and selection ofatmospheres which are oxidizing or reducing.

The CO₂ stream is passed directly through the thermal energy storage asthe principal heat transfer fluid. The solid media is heated byintermittently available renewable or grid electricity, and relativelycontinuously delivers a high temperature stream of CO₂ which may be at1000° C. or higher temperature and may deliver a significant fraction orall of the process energy required by kiln 76052 and preheater/calcinerunits. Each “unit” referred to may include one or multiple units to meetcharging, discharging or other requirements. The thermal energy storagemay not deliver high enough temperature or energy to the kiln 76052. Thecombustion of some fuel may supplement the energy flow and boost thetemperature to what the process requires. Therefore, the heating processmay optionally be a hybrid of heat derived from renewable electricityand heat derived from fuel combustion.

In one example implementation, this fuel combustion directly releasesits combustion gases into the kiln, avoiding the expense of heatexchangers. Those combustion gases include principally or only carbondioxide and water because an air separation unit has delivered arelatively pure stream of oxygen. In some example implementations, astoichiometric or near stoichiometric amount of oxygen may be used inburning of the fuel to create a stream of syngas (i.e., synthetic gas)containing a desired amount of carbon monoxide.

The produced syngas may be used in a separate water gas shift reactorsystem to produce hydrogen and carbon dioxide, which can be useddirectly as fuel or separated and productized. Accordingly, nitrogen isnot introduced into the gas stream flowing through the kiln, which mayyield an additional benefit of avoiding nitrogen oxide formation at hightemperature and making obsolete the non-catalytic reduction requirement(i.e., injection of ammonia solution into the kiln), avoidingunnecessary heating of a bystander gas such that a CO₂ separationtechnology is not needed in the process to separate CO₂ from nitrogen.

The combustion oxygen stream is optionally preheated to hightemperatures, such as 800° C. or higher, by a thermal storage unit R4 inwhich oxygen is directly flowing through the thermal storage media core.Optionally, the oxygen stream may be mixed with recycled flue gas(predominantly CO₂) to control the flame temperature and heat output ofthe combustion process. In another example implementation, the oxygenstream is mixed with both or either of flue gas (predominantly CO₂)and/or gaseous fuel before entry into the kiln combustion system.

By tuning the quantity of CO₂ mixed into the fuel stream, the heatingprofile can be controlled in a way to adjust, for example, fuelconsumption, product production, quality and system configuration toallow retrofitting of existing kilns. The fuel, whether methane,propane, hydrogen, or other fuel, optionally combined with recycled CO₂stream, may be preheated by a separate thermal energy storage R3 inwhich the fuel gas flows directly through the thermal energy storagecore.

This preheating allows the heat released by combustion to deliver onlythe high temperature heat, with lower temperature heat needed to heatthe oxygen and fuel provided by captured thermal energy. Theconstruction materials used in thermal energy storages R3 and R4 may bethe same as those in storages R1 and R2 or may be different so as totolerate the gas composition(s), temperature requirement or to improveperformance, cost, durability, chemical interactions or otherparameters.

In one implementation, the result of the foregoing example operations isthat between storage R1 and combustion of fuel and oxygen optionallyheated by storages R3 and R4, high temperature CO₂ streams deliver thekiln heat required by the kiln reaction steps. The kiln exhaust gasstream is comprised principally of CO₂ (potentially with H₂O fromcombustion, if any). This gas stream is optionally combined with anothersuperheated CO₂ stream carrying high temperature heat at point C andintroduced into the calcination and preheating process 76054, heated bythermal energy storage R2. In the calcination process, additional CO₂ isreleased, and thus a higher volume of CO₂ flows at D. The gas stream atD may be cleaned of particulate matter by, for example, a cycloneseparator and/or ceramic filter. The gas stream is divided, with oneportion returned to thermal energy storages R1 and R2 where it isreheated to continue to deliver heat into the process, and anotherportion partially cooled and extracted as captured CO₂.

In one implementation, a control system matches the rate of CO₂extraction and compression to the rate of CO₂ production in thecalciner. That control system may use measurements of the relative gaspressure in the various process units or other ordinary means to controlthe rate of gas extraction. Two heat exchangers H1 and H2 are shownwhich may cool the CO₂ by releasing heat to the environment or may coolthe CO₂ and use the heat for another purpose, for example drying of rawmaterial or heating input CO₂ stream for R2. This example operationallows for energy recovery even when the rawmill is not operational, asthey tend to run intermittently to ensure a surplus of raw material tokeep the kiln running continuously.

Alternatively, a separate TES system (not illustrated) may be coupled tothe rawmill operation such that the drying process is powered from thethermal energy storage. The thermal energy storage may be chargedconvectively by exhaust at D or electrically. The cooled CO₂ may becompressed, captured and stored or used for another purpose. Because thestream almost entirely consists of CO₂ and potentially water, waterremoval through a condenser would produce a pure stream of CO₂ ready forcompression. Optionally, a relatively inexpensive CO₂ purification unitmay be used. In comparison, MEA absorption requires a considerableamount of energy for regeneration and fans and pumps.

FIG. 78 illustrates an example implementation 76060 of a kiln 76062 andprecalciner R decoupled system. The hot exhaust air from the rotary kilnis decoupled from the preheat/precalciner inlet. The heat recovered fromthe cooler for the hot clinker may or may not be fed into theprecalciner.

In another optional example implementation, thermal storage system R2 oranother heat system provides heat for the treatment of cement kilnbypass dust (CBPD) to increase product yield, reduce carbon emission andreduce costs associated with landfilling or otherwise disposing of thematerial. The separated or addition of salts may be beneficial asadditives to the main material stream to lower the processingtemperatures, reducing the energy and temperature requirement to formthe desired product, potentially further reducing the need for fuelfired heat topping and allowing renewable energy to power a largerfraction of the cement production process.

FIG. 79 shows an implementation 76070 that uses waste heat from cementproduction process exhaust to provide economizer heat in a thermal cyclepower generation system. As shown, an electrically heated thermal energystorage R5 may produce superheated steam, supercritical carbon dioxide,or another heated working fluid driving a turbine power generationcycle. An electrically charged thermal energy storage unit delivers ahigh pressure, high temperature stream—superheated steam, carbondioxide, or another working fluid-driving a turbine which powers thegeneration of some or all of the electricity used at the facilityrelatively continuously. The thermal generation cycle reject-heat flowsto an air- or water-cooled condenser, and the cooled condensate orreturn gas is then pumped to high pressure.

Heat exchangers H1 and H2, which capture heat from the carbon dioxidestreams, may release heat into the feedwater or inlet gas stream for thepower generation cycle, thus capturing that otherwise waste heat as aheat recovery economizer in the power cycle. In various implementations,that power cycle may be a simple steam turbine cycle, an organic Rankinecycle, a supercritical carbon dioxide (sCO₂) cycle, or it may be acombined cycle power generation system, including a combustion turbinewhose exhaust is captured to drive a second thermal cycle.

In one example implementation, the combustion turbine is oxyfuel blownand its exhaust gas CO₂ is introduced back to the overall CO₂ cycle,eliminating any separate CO₂ emissions from the power generation. Thethermal energy storage R5 may be integrated into that combined cycle asshown. In one example implementation, supercritical carbon dioxide isused as the working fluid inside the heat storage unit and can directlyrun a sCO₂ power cycle or be used for another application.

The CO₂ stream extracted from the cement manufacturing process may beused for multiple purposes, including geologic sequestration,carbonation of supplementary cementitious materials, or as an element inthe production of synthetic fuels.

Another example implementation includes a steam cycle for continuouspower generation and additional heat recovery. In such animplementation, hot air from the cooling cyclones or a screw heatexchanger in contact with the hot calcined product exchanges heat withpressurized, recycled water from the steam cycle and some makeup water.This cooled gas/air is either released to the environment, used in thedrying part of the process, or introduced as cool gas in a TES system.The preheated water is turned into steam via heat exchange with a TESsystem. This may be the same TES system involved in the calcinationprocess or a supplementary unit. The air side of this heat exchange iscirculated back into the TES system to reduce waste heat. The steam isthen expanded in a steam turbine, generating electricity for the plant.The steam downstream of the steam turbine may exchange heat one lasttime with air or gas for use in the drying process before being mixedwith any feed water makeup, pressurized and recirculated in the cycle.

FIG. 80 shows an integration 76080 of a solid oxide electrolyzer whoseoperation is maintained by heat stored in a thermal energy storage R6,and whose operation may be advantageously efficient by being maintainedat beneficial temperature, with the thermal energy storage providingthermal energy that is absorbed in an endothermic electrolysis reaction.

Such a solid oxide electrolyzer may electrolyze water to producehydrogen or may co-electrolyze a flow of steam and carbon dioxide, suchthat its outlet products are carbon monoxide and hydrogen, or syngas.The relative flow of CO₂ and H₂O may be so adjusted as to produce thedesired proportions in the syngas of carbon monoxide to hydrogen. Thedesired syngas composition may also be attained by controlling thecombustion and stoichiometry of the fuel fired inlet. The syngas may beused for a variety of purposes, including the drive of Sabatier orFischer-Tropsch reactions to make various hydrocarbon molecules, or awater gas shift reaction producing H₂ which may be used as fuels orfeedstocks in other industrial processes.

The solid oxide electrolyzer (SOEC) may be integrated with thermalenergy storage R6 in gas contact with the fluid flowing through thethermal storage core, where that circulating fluid is air. In oneimplementation, the SOEC may be swept by air at a higher temperature,such as 830° C., and the air exiting from the SOEC may be at a lowertemperature such as 800° C. The heat in that air is then captured by aheat recovery unit to generate steam or heat another working fluid foranother purpose. That heated fluid may for example be integrated intothe electric power cycle previously described. The operation for theSOEC releases oxygen into the air sweep.

To manage overall oxygen concentration, relatively cooler air comingfrom the heat recovery unit is partially released, and ambient make upair is partially drawn into the thermal energy storage. This releasedgas is oxygen enhanced air. This stream may be supplied to an airseparation unit, an alternative feedstock to the air separation unit,storage unit or fuel firing units shown on FIGS. 77 through 79 as ameans of mitigating their electric power consumption and improving theiroutput. Hydrogen or oxygen produced may be stored in tanks orunderground caverns for future use or sale.

As shown in FIG. 81 , combustion-based approaches 76100 may beassociated with implementations of a calcination process. In oneimplementation, the raw material, such as the clay minerals, is providedat 76101. The raw material is fed to a dryer/crusher at 76103. At 76107,the crushed and dried clay is fed to preheat cyclones 76107. At 76109,the product that was fed through the cyclones and preheated with hot gasat 76107 is provided to a calcination chamber 76109. The calcinationchamber 76109 is heated with hot gas provided from a combustion chamber76113, which is provided by fuel from a burner 76111. The gas steam mayalso be provided to the preheater cyclones 76107, dryer/crusher 76103and filter and exhaust stack 76105. At 76115, the product is reduced ina reducing zone 76115, which may be powered by supplementary fuel 76117.Then, the reduced product is provided to cooling cyclones 76119, whereambient air 76121 is provided for cooling. An activated material, suchas activated clay for making cement, is provided at 76123.

The foregoing approach is modified by the integration 76150 of a thermalenergy storage system as shown in FIG. 82 . Elements having similar orsame depictions as FIG. 81 are not repeated. More specifically, insteadof using fuel to provide air via combustion, the thermal energy storagesystem 76163 provides hot gas heated by radiative heating fromelectrical energy. Thus, it is not necessary to use fuel for combustion.Accordingly, the above-mentioned problems associated with moisture fromthe combustion process may be avoided. Additionally, a baghouse filter76155 is used as an output of the dryer/crusher 76153, and the gasbyproduct of the baghouse filter 76155 is provided to an exhaust stack76157 and to the thermal storage system 76163 as an input. The byproductgas from the cooling cyclones 76169 is also provided as an input to thethermal energy storage system 76163. The structures and operationsassociated with the other features, such as the dryer/crusher 76153,preheat cyclones 76159, the calcination chamber 76161, the reducing zone76165, the supplementary fuel 76167, the cooling cyclones 76169, andambient air 76171, are similar to those explained above with respect tothe other approaches. In one implementation, the raw material, such asthe clay minerals, is provided at 76151. An activated material, such asactivated clay for making cement, is provided at 76173.

As noted above, the TES system may be used to provide heat into thecalcination step of the-Bayer alumina process. Additionally, the heatinputs into other parts of the process may also replace fuel, includingthe fuel that is provided at the mine, at the lime kiln, and at thesteam generator that provides energy to operate these modules.

With respect to the calciner stage, art approaches perform calcinationin two stages: a first stage at a lower temperature associated with adecomposer and steam separation to perform partial, and a second stageat a higher temperature than the first stage, but at a lower temperaturethan would be required if calcination was performed in a single stage.The first stage may be at a temperature such as 350° C., and the secondstage may be in the range of 750° C. to 950° C. The two-stagecalcination process provides energy efficiency advantages over a singlestage calcination process. Similar to clay calcination, a fuel isprovided as an input to the first calcination stage and the secondcalcination stage. The heat that is output from calcination may beprovided for reading and waste heat recovery, with the remaining heatbeing expelled after water cooling via stack gas output.

Conventional calcination involves heating the cooled, wet gibbsite to950° C.-1100° C. to remove free and crystalline moisture in thegibbsite, which is derived from bauxite. Art approaches have used arotary kiln or calciner using heat from combustion. According to someart approaches, the material first enters a high-pressure calcinationstep (e.g., the decomposer), for example at 6-8 bar and 300° C.-480° C.,and removes all the free moisture (e.g., drying) and activates asignificant portion of the gibbsite to alumina. These mechanisms producewater vapor as effluent. The partially calcined material passes througha pressure reducer to the lower pressure calcination stage. This occursat ambient pressure and relatively lower temperatures of 850° C.-950° C.Fuel and air that is preheated in the cooling of the product material iscombusted in a gas suspension calciner. The heat from the flue gas isfurther recovered by being passed into a steam generator/superheaterwhere is exchanges heat with recycled steam from the first stage,recycled steam from other steps in the Bayer process, or makeup water tosupply the first calcination step (or decomposer) with superheatedsteam.

These approaches may have problems and disadvantages. For example, whensteam is used as a heat transfer medium in calcination stage, it isnecessary to account for the plant balance, as the extremely high massflow of superheated high-pressure steam must be filtered and cleanedbefore recirculating to other areas of the plant. The theoretically morefavorable heat balance from collecting high temperature moisture fromthe decomposer also translates to a more complex, integrated process.The large mass flow leads to art problems in supplying the correctquantity of superheated steam. The steam generator/superheater is amajor area for concern, both from the thermodynamic and operatingstandpoint. Additional fuel must be fired in this step. Additionally,buildup in process equipment is one of the largest issues in theconcept, as the recirculated steam often must be cleaned and filtered ofparticulate matter before interacting with the steam generator andsuperheater.

To address these problems and disadvantages, the thermal energy storagesystem described above supplies heat to recirculating process steam, andmay be integrated with heat recovery apparatuses to address art plantbalance problems. For example, heat from the hot flue gases of thesecond gas suspension calciner may be utilized to supply a portion ofthe heat to either the thermal storage working fluid medium (e.g.,gas-to-gas heat exchangers) or the process steam (e.g., gas to liquidheat exchanger). This will allow the plant greater flexibility in energymanagement as well as maintenance to fix solid buildup in heat transferequipment. The thermal battery may be external to the plant and mayeither supply steam externally with an attached steam generator orsupply steam indirectly, passing hot gases through existing or new heatexchangers replacing the duty of combustion gas products.

In another example implementation, the thermal storage relates to afully integrated process where the thermal batteries replace allcombustion on site. This implementation includes the above-describedapproach, with supplying all or the majority of the heat to the secondcalcination stage. The temperature of the partially calcined material isbrought to near ambient pressure (from the high-pressure stage 1) andput in direct contact with hot flue gases bringing the temperature to850-950 C. This reduced temperature range allows the heat from firedfuels to be replaced by high temperature stored heat.

In some example implementations, the primary working fluid of thethermal energy storage system would contact the material to be calcined.In other example implementations, this heating may occur indirectly,where the primary working fluid of the thermal battery does not directlycontact the material. The hot gas would be blown through the calciner atsufficiently high velocities to achieve desired level of suspension andactivation. The gas effluent would leave the chamber at a hightemperature to be used in the steam generation and superheating of theprocess steam used in the first stage of calcination as well as anyother steam needs in the system.

As shown in FIG. 83 , a calciner process 8300 associated with aluminumproduction according to the example implementations has severalmodifications to prior approaches. The thermal energy storage 8301provides a heat input to the second calcination stage 8303. Thus,instead of using fuel to generate that heat, such as by combustion inother approaches, the heat is provided as hot gas from the TES system asexplained above. A high volume of high temperature hot gas is providedas an input to the second calcination stage at its operatingtemperature. Thus, it is not necessary to provide preheated air fromalumina cooling 8311, as may be required in prior approaches.

The output byproduct of the second calcination stage 8303 is slightlycooled gas that can be used for the heat recovery steam generator 8307,instead of the additional fuel and air that may be present in the priorapproaches. The steam output from the steam generator 8307 is providedto the first calcination unit 8309 at the temperature of the firstcalcination unit 8309, which may provide the recycled steam flow andsolids as in the prior art. Additionally, instead of expelling excessheat or waste heat from the steam generator as a set gas, the heatbyproduct of the steam generator is the gas that has passed through aheat recovery zone, and is injected into the alumina cooling cyclones8311, along with ambient air. The byproduct heat from the aluminacooling cyclones is provided, through a baghouse and filter 8317, as therecirculated gas for the input of the thermal storage unit.

According to an alternative implementation, the TES system may only beused for providing the heat for the steam generator, so that theexisting infrastructure of the alumina processing facility can be usedwithout substantial modification.

The example material activation system may have various benefits andadvantages. For example, because the output of the waste heat recoveryis recirculated as an input to the thermal energy storage, emission ofheat through the stack is avoided. Thus, unnecessary heat emissions tothe atmosphere can be avoided. Additionally, by using the incoming heatfrom the TES system, it is not necessary to use fossil fuel to providethe input heat. Further, because the combustion aspect of generatingheat is removed, the free moisture in the input combustion stream iseliminated, which avoids the problems introduced by the presence of thatmoisture, particularly with respect to the calcination of clay, asexplained above. The example implementation also has a benefit of morefavorable thermodynamics and lower maximum temperatures.

3. Advantages Over Prior Systems

The material activation system described herein may have variousadvantages and benefits over prior calcination implementations. Forexample, the material activation system may reduce or eliminate carbondioxide emissions associated with cement manufacturing, by runningpartially or exclusively on renewable electricity using thermal energystorage arrays heated by electric power.

Further, the modularity of the thermal energy storages and applicabilityin various parts of the cement production process allows for stepwiseelectrification, retrofitting and hybridization with fuel firing.Integration of thermal energy storage allows low cost, low carbonintensity, low capacity factor electricity to operate various processesin cement production or other industrial applications at high annualcapacity factors that may be nearly equivalent to operation with fossilfuels.

The material activation system described herein also addresses problemsassociated with moisture in clay. Clay is generally a very moistsubstance as it is often acquired in wet areas with relatively largeamounts of both free moisture and crystal water in the structure of themineral. The fuel consumption in the activation rises dramatically withthe amount of free moisture present in the clay, due mostly to energybeing wasted on a water phase change. This problem is further compoundedby additional water vapor produced in combustion. The TES system,however, overcomes this problem as combustion is not the primary form ofheat transfer. Not relying on combustion also allows the thermal storagesystem to have a higher degree of freedom in operating conditions sincethe air flow rate will not dramatically change the gas compositioninside the reactor chamber.

Another benefit to switching from combustion to electrically heated andstored energy is that, in clay activation, there exists an upper boundtemperature at about 950° C., e.g., 950° C. where the clay mineralstructure is destroyed to mullite and loses all of its desired qualitiesfor use as an SCM. In combustion-driven processes, temperature profilesinside of reactors are much harder to control than with a fixedtemperature gas heat source that is much easier to control and monitor.

By decoupling the hot exhaust air from the rotary kiln from thepreheater/precalciner inlet, one or more multiple potential benefits maybe achieved. By decoupling the gas flow between the kiln andprecalciner, gas flow and heating rates can be independently controlledto optimize each process. For example, in an air-through system, theamount of fuel that can be burned at the calciner can be limited due toexcessive gas flow rates that can cool the flame temperature. Also, theheated exhaust gas from the kiln can be captured and used foralternative purposes, such as providing thermal energy to a power cycleto generate electricity.

Further, the hot exhaust from the kiln may contain significant amountsof undesirable components such as alkali salts, which evaporate in thehotter sections of the kiln. These undesirable components may causedamage to equipment, cause clogging in the precalciner as it cools andreduce quality of the product as it recirculates. By decoupling the kilnand precalciner, the undesirable byproducts can be kept out of theprecalciner and potentially captured. Additionally, heat required forthe precalciner can be provided from a TES system powered by renewableenergy or other sources, and optionally supplemented by a fuel firedsource.

As another benefit, the kiln and precalciner can be run on different gasmakeups in some implementations. For example, the kiln may be heated byan oxyfuel energy source with added methane, resulting in a gas makeupconsisting of predominantly CO₂ and H₂O. This makeup avoids sidereactions such as that of air nitrogen with oxygen, producing nitrogenoxides. Carbon dioxide and water can be utilized in processes describedelsewhere in this disclosure. The precalciner can be run on air flowingthrough the thermal energy storage as it may be less expensive and maynot have the problem of nitrogen gas reactions. The type of gas andcombination of storage versus fuel energy source can be independentlyadjusted and potentially optimized in some embodiments.

The use of carbon dioxide has various benefits and advantages. Forexample, carbon dioxide does not require an air separator and hasthermal properties that are more conducive to heat transfer. Carbondioxide also has a higher emissivity at high temperatures. Further,carbon dioxide is inert and does not combust, which as stated at thebenefit involved. Because the carbon dioxide does not react with theresistive heaters, there is less oxidation or wear and tear on theresistive heaters of the thermal energy storages. The byproduct gas isrecirculated as input fluid for the TES system, and carbon dioxide isnot released into the atmosphere, which has an environmental benefit ofreducing greenhouse gases.

Prior approaches do not include an integrated process that uses hotgases generated from electric resistive heaters to supply all of theheat for a calcination process. Further, these approaches do not includean integrated process that uses a TES system that charges fromelectricity and discharges heated fluid directly into aflash-calcination process as the main mode of heat supply. Additionally,the material activation system may recirculate waste gases from thematerial heating system back to the TES system. This recirculated fluidmay also have a desired composition to meet reaction and quality needs.

B. Electrolysis

The gas that is output from the TSU may be provided as the input forvarious industrial applications. One type of industrial application thatuses and benefits from a continuous stream of heat at a constanttemperature is electrolysis. The thermal energy storage system receivingelectric power that can flow into a heat storage system (e.g., takingair in at 200° C. and delivering air in a range between 600° C. and 900°C. (such as 860° C.) when discharged for electrolysis). As explainedbelow, art electrolysis systems can be improved by combination with theabove described thermal energy storage system.

1. Problems to be Solved

Solid oxide electrolyzers according to conventional designs receive aninput of heated gas and water in the form of superheated steam. The gasis heated prior to input to the solid oxide electrolyzer by an electricresistive heater, a fuel heater, or the like. The use of an electricresistive heater or fuel heater for this purpose may have variousproblems and disadvantages. For example, fuel heaters may consume fossilfuels such as natural gas, which is expensive and causes pollution.Electric heaters powered directly by VRE sources cause problems withchanging temperatures and limited operating periods.

There are several types of fuel cells that take hydrogen or a mix ofgases and make electric power, such as molten carbonate electrolyzerfuel cells, and solid oxide fuel cells. Such fuel cells use essentiallythe same as electrolyzers in reverse. However, solid oxide fuel cellshave problems and disadvantages because the oxidation causes localizedheating and issues with cell life. Solid oxide fuel cells require theirinlet reactants and the fuel cell assembly to be maintained atparticular temperatures. The operation of fuel cells delivers energypartly in the form of electrical energy and partly as heat. Further,solid oxide fuel cells require a recuperator (e.g., high temperatureheat generator) to make use of a portion of the heat generated by thefuel cell. However, a substantial portion of the heat so generated isnot used, which results in inefficiencies.

2. Reversible Solid Oxide Unit

Solid oxide electrolyzers may include an electrolyzer producing hydrogenby using electrical energy to break apart the molecular bonds and driveapart the elemental ions that into separate outlet streams. Solid oxideelectrolyzers have a porous cathode with a porous electrolyte that iscatalytic when operated at temperatures at or above 830° C., and thermalenergy is contributing to cracking those bonds. A solid oxide fuel cellis typically 40-50% efficient at taking fuel energy and making electricenergy, with the rest of the energy being released as heat at around850° C., e.g., 850° C. to 860° C., e.g., 860° C., in some cases, whichare slightly higher temperatures than the optimal operational point forthe solid oxide electrolyzer. A system may incorporate one or more solidoxide electrolyzers and one or more solid oxide fuel cells; a singlesolid oxide unit may operate reversibly as an electrolyzer or fuel cell.

FIG. 84 provides an illustration 4300 of the solid oxide unit as a fuelcell 4301 and as an electrolyzer 4303. The solid oxide fuel cell at 4301receives as its input a gas such as hydrogen or carbon monoxide. Thehydrogen or carbon monoxide is combined with oxygen enriched gas acrossa potential to output electrical energy 4305 and either water or carbondioxide, depending on whether hydrogen or carbon monoxide, respectively,is the input. Similarly, as shown in the solid oxide electrolysis cell4303, water or carbon dioxide is provided as an input along with heat inthe form of hot fluid from the thermal energy storage system, whichobtains its energy from an electrical source such as the renewable windsource 4307 as illustrated. The output is hydrogen gas or carbonmonoxide, depending on whether water or carbon dioxide was the input, aswell as oxygen enriched gas as a byproduct.

FIG. 85 illustrates the electrolysis mode 4900 of the exampleimplementation. The thermal energy system 4901 receives electricalenergy from a source, such as a VRE source 4903, and/or from anothersource, either locally or via an electricity grid 4905. The electricitysource 4903 may also be coupled to other elements of the solid oxideelectrolysis system, for example, to provide electrical potential forthe electrolysis reaction. Fluid 4902 (e.g., hot air) is output from thethermal energy storage system 4901 and provided to the solid oxideelectrolysis cell 4907. Fluid 4902 may be at a temperature between 800°C. and 900° C. (such as 850° C.). Solid oxide electrolysis cell 4907 mayalso receive steam 4904, which may be at a temperature near fluid 4902(for example, 830° C.). The solid oxide electrolysis cell 4907 mayreceive electricity from the electricity source 4903 and generate as itsoutput hydrogen as the product gas 4908 along with oxygen enriched hotfluid 4923 as a byproduct.

The product gas 4908 (e.g., hydrogen) is cooled via a heat exchanger.The heat exchanger may reject heat to the environment or, moreefficiently, may deliver heat to a thermal load, such as a once-throughsteam generator (OTSG) 4911, as its input. The product gas flows throughthe heat exchangers of the OTSG 4911, which is supplied by cold waterfrom a source 4913. As the product gas 4908 is cooled by the heatexchanger/OTSG 4911, much of its carried water is condensed, becomingcondensed product gas 4912. The condensed product gas 4912 is primarilyprovided to a hydrogen processing unit 4915, which in turn provides thehydrogen gas in a storage ready form to storage 4917. A portion of thecondensed product gas is recirculated at 4919 to be mixed with the inputsteam 4904. In one implementation, steam 4904, or a portion of thesteam, may be the output of the OTSG 4911, as shown at 4921.

In a manner similar to that explained above for OTSG 4911, another OTSG4931 may be provided, having water supplied from a source 4933. Aspreviously discussed, the OTSG 4931 may be any heat exchanger heating afluid, including a recirculating boiler with or without superheat, or aunit that heats circulating air, CO₂, oil, water, or salt. The OTSG 4931receives the oxygen enriched hot fluid, and outputs the cooled fluid at4937. In some implementations, the OTSG 4931 may receive another streamof hot fluid from the thermal energy system 4901 so as to adjust thetemperature or heat flow of the combined stream to a more usefulcondition. The cooled, oxygen-enriched fluid 4937 may be mixed withambient or preheated air at 4935, to adjust the composition of oxygen toa desired level. The adjusted fluid 4939 may be provided as an input gasto the thermal energy storage system 4901.

FIG. 86 illustrates the fuel cell mode 5000 according to an exampleimplementation. The thermal energy storage system 5001 provides air oroxygen as shown at 5002, such as explained above with respect to theelectrolysis mode. Separately, a supply of hydrogen 5003 is provided.The hydrogen is heated up via the single pass heat exchanger 5005 by thehot fluid from the thermal energy storage system. Optionally, a smallamount of steam may be mixed in with the hydrogen gas to avoiddegradation of the solid oxide unit. The fluid from the thermal energystorage system may be provided at a temperature that is lower than thatof the electrolysis mode, such as 650° C. or in a range between 600° C.and 700° C.

In the fuel-cell mode of operation, the air 5030 may provide a coolingeffect in solid oxide fuel cell 5007. The air 5002 from the thermalenergy storage system 5001 and the heated hydrogen from the hydrogenstorage 5003 are input as shown by 5004 and 5030 respectively to thesolid oxide fuel cell 5007. As its output, the solid oxide fuel cell5007 generates direct current electricity at 5006. In oneimplementation, the direct current electricity is provided to aninverter to convert to an alternating current power output, which can beprovided to any use 5009 (which may, e.g., be a power grid). Additionaloutputs of the solid oxide fuel cell 5007 include water and hydrogen asa product fluid at 5011, and heated, oxygen-depleted air at 5021. Theproduct fluid at 5011 is provided to heat exchanger 5013, which coolsthe product fluid by heating another fluid which may be water, air, oranother fluid received as shown at fluid source 5015.

The output includes export steam, which may be provided as an input toan industrial application that requires steam, such as a steam turbineas explained above. Additionally, residual hydrogen may be recirculated,by way of a heat exchanger 5005, to the solid oxide fuel cell 5007, asshown at 5027. The oxygen-depleted fluid 5021, optionally supplementedwith other hot fluid from the storage 5031, is provided as the heatinggas for the heat exchanger 5013, and subsequently provided as the inputfluid for the thermal energy storage system 5001, as shown at 5025. Itis noted that the solid oxide fuel cell 5007 generates electricity andheat. Thus, the input fluid from the thermal energy storage system 5001,which is at about 650° C., e.g., 650° C. in this example, is provided ascooling air for the solid oxide fuel cell 5007.

FIG. 87 illustrates an example system 4100 used to power the productionof hydrogen and/or hydrocarbon fuels by delivering both heat and powerto drive a high-temperature solid-oxide electrolyzer. Solid-oxideelectrolyzers can reduce the electrical energy input needed per unit ofhydrogen by harnessing thermal energy to drive the breaking of chemicalbonds. Relatively higher total efficiency may be achieved by directing aportion 4101 of the high-temperature stored heat from thermal energystorage system 4105 as high-temperature heat to an electrolyzer 4102which is also fully or partially powered by electricity 4103 generatedby a thermal generation process 4104. Thermal generation process 4104may include, for example, a Rankine cycle or supercritical CO₂ cycle.

In some implementations, the electrolyzer 4102 may co-electrolyze waterand CO₂ (separate electrolyzers may also be used to electrolyze waterand CO₂) with all or a portion of the resulting syngas directed to amethanation or Fischer-Tropsch type conversion unit 4109. Unit 4109 maymake a synthetic gaseous or liquid hydrocarbon fuel, shown at 4106.Additionally, a once-through steam generator (OTSG) 4107 may be providedas a condenser that cools the output fluid of the solid oxideelectrolysis unit 4102 and provides the steam as an input to the solidoxide electrolysis unit 4102. The byproduct hot fluid is recirculatedback to the thermal energy storage system 4105 as an input fluid.

As explained above, the electrolyzer is reversible as a fuel cell. Thus,when the renewable input power such as the photovoltaic array isunavailable or when electricity is needed by the grid, hydrogen can befed to the fuel cell and water, electricity, and heat can be output fromthe system. The heat is at a high enough temperature that the heat canbe used to produce steam or utilized in another industrial process.Accordingly, less heat is extracted out of the heat storage unit as itis replaced with what would otherwise be waste heat coming from the fuelcell.

Alternatively, the gas flow can be reversed, and heat can be putconvectively back into heat storage. Thus, when the system is performingco-generation and running heat, the waste heat from the fuel cell can beused to either displace energy that would otherwise have been dischargedfrom heat storage or be returned to heat storage.

The efficiency in the electrolyzer dramatically improves when using hotfluid from the thermal energy storage system. Further, if none of theoutlet steam is being used, the captured heat can be repurposed. Forexample, hydrogen is produced in one implementation, with a fractionbeing sold and another fraction being used for power generation. Thewaste heat from power generation may be recaptured and used to reducethe electricity used for electrolysis during the next period, such asthe next day. Further, in some example implementations, one or both ofthe convective waste heat from the fuel cell and input electric heat maybe used to charge the thermal storage unit.

In one implementation, the system may incorporate 1) a solar array orother intermittent electricity source; 2) a combinationelectrolyzer/fuel cell-heat storage unit; and 3) a lithium-ion batteryand an electric vehicle charging station and a hydrogen filling station.This system can be used to store energy as hydrogen that may participatein providing the off-hours electricity for EV charging but is alsoavailable for dispensing to vehicles as hydrogen charging.

FIG. 88 illustrates a reversible solid oxide electrolysis system 4800according to an example implementation. The thermal energy storagesystem 4801 provides hot fluid (e.g., hot gas) 4809 at its output. Asshown in this example, the composition of the fluid is 53% nitrogen gasand 47% oxygen gas, at a temperature of 855° C. and a flow rate of 1620kg per hour. However, the composition of the oxygen or nitrogen can beadjusted based on the operating parameters of the solid oxide cell 4803.For instance, the gas may have an oxygen volume percentage between 25%and 60%. Additionally, the temperature or flow rate may be varied. Forexample, the temperature may be between 800° C. and 900° C. or the flowrate may be between 1500 kg/hr. and 2000 kg/hr.

The hot fluid 4809 is provided to a solid oxide unit 4803. In this case,the solid oxide unit is a two-way reversible unit. For example, solidoxide unit 4803 can operate in electrolysis mode, which produces anendothermic reaction, or in fuel cell mode, which produces an exothermicreaction. The solid oxide unit 4803 is currently described inelectrolysis mode. The solid oxide cell 4803 in electrolysis modereceives the hot fluid 4809 from the thermal energy storage system 4801.Because the solid oxide unit 4803 in electrolysis mode operates suchthat the internal resistance does not generate enough heat to overcomethe endothermic reaction, the solid oxide unit 4803 is operating inthermal neutral voltage mode. Although it is not shown, each of thecells receives an electrical input at 1.28 V. Other voltages may also bepossible such as a voltage in a range between 1 volt and 3 volts. Invarious embodiments, hot fluid 4809 is passed through the solid oxidecells as a sweep fluid (e.g., sweep gas).

In addition to the hot fluid 4809 (e.g., sweep fluid) provided by thethermal energy storage unit, a reaction fluid (e.g., steam mixed withhydrogen) 4811 is also provided as an input to solid oxide unit 4803. Inthis example, the reaction fluid 4811 is provided having 96% water and4% hydrogen gas, at a superheated temperature of 807° C. and at a flowrate of 814 kg per hour. The percentage of water, temperature, or flowrate of reaction fluid 4811 may be varied. In various implementations,the temperature of reaction fluid 4811 is at a temperature below hotfluid 4809 but at a temperature above 800° C. In some implementations,the flow rate of reaction fluid 4811 is balanced with the flow rate ofhot fluid 4809 to provide desired reaction results in solid oxide unit4803.

The reaction fluid 4811 is provided to the solid oxide unit 4803. As aresult of the reaction in the solid oxide cell, the water molecule issplit and the resulting ions form oxygen gas and hydrogen gas. At thesame time, the sweep gas (e.g., hot fluid 4809) pulls the oxygen off ofthe air electrode as the water comes in on the cathode and strips theoxides off of the water.

As outputs, the solid oxide cell in electrolysis mode produces productfluid 4813 as well as oxygen enriched fluid 4815 (e.g., oxygen enrichedair). In certain implementations, the temperature of the product gas isnear a temperature of the oxygen enriched fluid. Both fluids may be at atemperature between a temperature of the reaction fluid and atemperature of the hot fluid 4809. In the illustrated embodiment, theproduct fluid 4813 is 76% hydrogen and 24% water by volume, whichcorresponds to 26% hydrogen and 74% water by weight. The temperature ofthe product fluid 4813 is 830° C. and it is provided at a flow rate of274 kg per hour. The enriched fluid 4815 is a composition of 60% oxygenand 40% nitrogen by volume, at a temperature of 830° C., and at a flowrate of 2159 kg per hour. The composition, temperature, and flow rate ofthe product fluid 4813 and enriched fluid 4815 may vary based on theoperating conditions of the system.

For product fluid 4813, a thermal load such as an OTSG 4805 includingheat condensers is provided. OTSG 4805 uses water to cool and condensethe hydrogen gas. More specifically, the product fluid 4813 enters theOTSG 4805, where it is exposed to water that is run through pipes. Thesource of the water for the OTSG 4805 is a water reservoir 4817, wherethe water is provided at a relatively cool temperature such as 25° C. Asthe water passes through the various condensers, the water becomes moreand more heated from the exit to the entrance of the condenser. Morespecifically, the water reservoir 4817 provides the clean water andcondensate to a first stage of the heat exchanger, where the productfluid is at its coolest point of the three heat exchangers.

The water then flows to a second heat exchanger that is upstream of thefirst heat exchanger, and the product fluid is warmer than at the firstheat exchanger. At the third heat exchanger, the product fluid 4813 isincoming, and is at its hottest point. While the heat exchangers of thecondenser are shown as having three stages, the heat exchanger may bevaried to have more or fewer stages as a matter of design choice.

As a result of the heat exchange, the condenser operates as the OTSG4805, because as the water absorbs the heat from the hot hydrogenproduct fluid 4813, the water is converted to steam, and the steam isprovided to the input of the solid oxide unit at a temperature of around830° C., e.g., 830° C. The steam is then provided as 4837 and input tothe solid oxide unit at 4811. Because the solid oxide unit 4803 issensitive to contamination, the source 4817 of the water for thecondenser is purified water. Optionally, the purified water may becombined with the condensate output 1819 of the condenser.

As the hydrogen passes through the condenser, water is removed from thehydrogen gas as condensate due to the hot hydrogen gas passing over thecool pipes of the condenser. The output 4821 of the condenser is dryproduct fluid, namely dry hydrogen gas. The hydrogen gas is provided toan industrial application at 4823, as explained above.

At 4825, some of the hydrogen gas (e.g., knock-off hydrogen gas havingsome water mixed in) is fed back into the input of the solid oxide unit4803 in combination with the steam that is formed at the output of thecondenser as explained above. The hydrogen gas is combined with steam atthe input of the solid oxide because 100% steam cannot be input to thesolid oxide unit due to degradation issues. Optionally, the gas that isoutput from the thermal energy storage system may be provided at atemperature based on a parameter of the solid oxide electrolyzer, suchas the operating temperature.

Because the thermal energy storage system provides the constant flow ofheated fluid 4809 at the temperature required for the solid oxide cellin electrolysis mode, there is no need for electric resistive heaters asin prior systems. Thus, the solid oxide cell 4803 may be provided andused without a heater. However, electric resistive heaters (or otherheaters) may be optionally added, to provide temperature adjustments orcalibration at the entrance of the solid oxide unit.

As the oxygen enriched fluid 4815 is input to the OTSG 4807, the waterfrom the water reservoir 4827 interacts with the enriched fluid, in amanner similar to that described above for the product fluid. Thus, heatis transferred to the water that passes through the heat exchangers.Such water is output as steam at 4839 and provided to the input of thesolid oxide unit as part of reaction fluid 4811 along with the steamfrom the product fluid condenser and the recirculated hydrogen gas. Theenriched fluid may also be vented at 4831.

The enriched fluid is output at 4829. The enriched fluid is output tothe atmosphere as air at standard atmospheric composition at 4833.Additionally, oxygen enriched fluid may be recycled at 4835 afterblending with atmospheric air, such that the composition of the fluid is53% nitrogen and 47% oxygen, for example. This fluid is provided as aninput to the thermal energy storage system 4801, where it is heated inthe thermal storage arrays and provided as an output to the solid oxideunit as hot fluid at 4809, as explained above. Further, the blending ofthe oxygen enriched fluid with atmospheric air also has a benefit forthe thermal energy storage system 4801, in that problems anddisadvantages associated with having oxygen enriched fluid in thethermal energy storage system, such as potential oxidation ofcomponents, are avoided.

Additionally, the temperature of the heat that is generated by thethermal energy storage system may be provided to the solid oxide unit ata temperature that is thermally neutral. In other words, because the hotfluid 4809 is provided at an elevated temperature, such as 855° C., thesystem is in an isothermic condition, and the system does not have anynet heat demands. In other words, the chemical reactions in the solidoxide unit 4803 will cool the system, whereas the only resistance withinthe thermal energy storage system is from the heating elements thatgenerate heat from electrical energy. The result is that there is no nettemperature change and a substantially lower energy cost. Accordingly,there is cost savings in that it is not necessary to add additionalresistive heaters or fuel meters to the solid oxide unit to heat theincoming air. However, it should be noted that the electrolyzer need notbe operated at the isothermal temperature and may instead use heat thatis generated at a higher or lower temperature.

As noted above, the solid oxide unit is reversible, such that it can beused as an electrolyzer, as explained above, or as a fuel cell. The fuelcell operation may include, using the structures as explained above,with the thermal energy storage unit providing oxygenated enriched fluidthat is combined with compressed hydrogen to produce direct currentelectricity and water, as described herein.

Additionally, in some implementations, when the solid oxide unit is notoperating the hot fluid 4809 generated by the thermal energy storagesystem may continue to be provided through the solid oxide unit. Thebenefit of flowing such hot fluid through the solid oxide unit when thesystem is not in use is that the ramping down during the cooling processand the ramping up during the heating process before and after activeoperation (e.g., thermal cycling), respectively, is avoided.Additionally, the wear and tear on the unit during those processes isalso avoided and, in addition, the time and cost of cooling and heatingof the various components is reduced (such as the ceramic inside thesolid oxide unit). Further, it is possible to switch loads, between thedifferent modes of operation (such as electrolyzer and fuel cell),without shutting down and warming up the unit. In some implementations,the solid oxide unit may continue to be heated by hot fluid 4809 attemperatures around those utilized during fuel cell operations.

The composition of the fluid flowing within the thermal energy storageunit may be adjusted by the extraction of oxygen enriched fluid 4829and/or the introduction of ambient fresh air. The oxygen enriched fluidextracted may be used for another purpose, including the purificationand supply of oxygen for a commercial purpose.

In addition, hydrogen and oxygen production may be coupled with otherprocesses such as hydrogenation of CO₂ or CO to make liquid fuels orremediation of contaminated groundwater contamination using oxygen.Excess heat, such as from a Fischer-Tropsch process, could be used toconvectively charge or pre-heat fluid for the thermal storage unit.Other electrolysis processes benefitting from renewable electricity orthermal energy can also be coupled to the storage system. As an example,a direct co-electrolysis of CO₂ in combination with the water-gas shiftreaction and steam to produce syngas, which can further be processed ina Fischer-Tropsch reactor for conversion to hydrocarbons, is optimal ata temperature serviceable from a renewable energy storage unit, asdescribed above, and powered using the DC architecture describedpreviously.

Nickel-based electrodes may also be utilized to obtain methanation ofcarbon monoxide (e.g., Sabatier reaction), with the ratios of variouscomponent products being controlled by temperature, pressure, andconcentration of components in equilibrium. It may be particularlyvaluable to locate a facility that combines energy storage,Fischer-Tropsch, Sabatier, and co-electrolysis processes at abio-refinery (such as an ethanol refinery (that has a large supply ofbiogenic CO₂ available from the fermenter) or another processingfacility such as a renewable diesel refinery (which has CO₂ streamsarising from process units and has fuel production equipment that canpurify the products arising from the Fischer-Tropsch reaction).

The system may also be used in industrial loads such as renewable dieselrefineries, petroleum refineries, or oil fields where there is very highvalue for hydrogen that is participating in the chemical process. —Thereis also very high value for 24-hour, zero carbon electric power. Forinstance, instead of producing hydrogen and power at low efficiency,this set of systems allows conversion of essentially every kilowatt hourthat comes into the system either leaving as a kilowatt hour of enthalpyand hydrogen or a kilowatt hour of heat or a kilowatt hour ofelectricity with very high efficiency (for example, 96 percent totalsystem efficiency).

In various implementations, fluids that are flowing in and out of theheat storage unit can be directly coupled with the fluids that areflowing across one side of the electrolyzer (e.g., the oxygen side). Assuch integration of a directly heated contact and a directly cooledcontact may assist with integration of the fuel cell.

In addition to being connected to the solid oxide electrolysis cell, thethermal energy storage system having electric power that can flow into aheat storage system taking fluid in at 200° C. and delivering fluid at atemperature of 800° C.-1600° C. when discharged as explained above, suchas the system disclosed above, can perform district heating, driving ofturbines, cogeneration, or other industrial uses. For example, in thecase of the solid oxide fuel cell mode, the heat generated in theprocess of making electricity from a hydrogen input may be used as anindustrial output for a steam generator in one implementation. Further,the excess electricity generated by the steam generator may be combinedwith the electricity provided from the source, such as the renewablesource, as the electrical input for the thermal heaters of the thermalenergy storage system according to the example implementations.

3. Advantages Over Prior Systems

The solid oxide unit of the example implementations may have variousbenefits and advantages over prior designs. For example, the solid oxideunit described herein receives stored heat from the thermal energystorage system as its input, instead of requiring an external heater,such as an electrical resistive heater or a fuel fired heater. Thus, thecost of operation may be reduced and the amount of pollution may also bereduced.

Further, while art approaches may burn the oxygen byproduct at theoutput of the solid oxide unit to generate heat for the heater that theinput of the solid oxide unit, the example implementations do notrequire heat to be generated at the input of the solid oxide unit. Thus,the byproduct air is provided to the heat exchanger, without burning offthe oxygen.

The enhanced concentration of oxygen in the flow may contribute toreductions in the cost of secondary oxygen separation. Such solid oxideelectrolyzer integration with thermal energy storage has benefitsincluding significantly enhanced efficiency in the conversion ofelectrical energy to energy and hydrogen and enabling such highefficiency electrolyzers to be combined and used effectively withvariable supplies of renewable electricity. Accordingly, charging may beintermittent while temperature is held constant without continuous useof electrical power.

Also, a portion of the energy in the electrolytic process in this manneris supplied by stored heat. It is beneficial to do this because the timeat which electricity may be captured and stored may be separated fromthe time at which electricity is captured and used for electrolysis.When electric power is available, the electric power can be used to heatcharge the storage system and also drive electrolysis to convert waterto hydrogen. Existing electrolyzers cost around $500-600/kW, whereasheat storage systems may be significantly less expensive. Heat storagemay be less expensive on a per kilowatt basis than electrolyzer stacksand it may therefore be less costly to pull power in at a very high rateduring periods of lower-cost power availability and apportion the powerbetween the heat storage and the electrolyzer. The electrolyzer can bemade to run longer and the peak load or the peak power can be droppedquickly into heat storage. Thus, there is a matching of electrolyzercapacity factor and cost against the availability of variable renewableelectricity

C. Thermoelectric Power Generation

1. Problems to be Solved

Gasification is the thermal conversion of organic matter by partialoxidation into gaseous product, consisting primarily of H₂, carbonmonoxide (CO), and may also include methane, water, CO₂ and otherproducts. Biomass (e.g. wood pellets), carbon rich waste (e.g. paper,cardboard) and even plastic waste can be gasified to produce hydrogenrich syngas at high yields with high temperature steam, with optimumyields attained at >1000° C. The rate of formation of combustible gasesare increased by increasing the temperature of the reaction, leading toa more complete conversion of the fuel. The yield of hydrogen, forexample, increases with the rise of reaction temperature.

Turning waste carbon sources into a useable alternative energy orfeedstock stream to fossil fuels is a potentially highly impactfulmethod for reducing carbon emissions and valorizing otherwise unusedcarbon sources.

2. Thermoelectric Power Generation

Indirect gasification uses a Dual Fluidized Bed (DFB) system consistingof two intercoupled fluidized bed reactors—one combustor and onegasifier—between which a considerable amount of bed material iscirculated. This circulating bed material acts as a heat carrier fromthe combustor to the gasifier, thus satisfying the net energy demand inthe gasifier originated by the fact that it is fluidized solely withsteam, i.e. with no air/oxygen present, in contrast to the classicalapproach in gasification technology also called direct gasification. Theabsence of nitrogen and combustion in the gasifying chamber implies thegeneration of a raw gas with much higher heating value than that indirect gasification. The char which is not converted in the gasifyingchamber follows the circulating bed material into the combustor, whichis fluidized with air, where it is combusted and releases heat which iscaptured by the circulating bed material and thereby transported intothe gasifier in order to close the heat balance of the system.

Referring to FIG. 6 , in some example implementations, the thermalenergy storage structure 503 can be integrated directly with a steampower plant to provide an integrated cogeneration system 500 for acontinuous supply of hot air, steam and/or electrical power for variousindustrial applications. Thermal storage structure 503 may beoperatively coupled to electrical energy sources 501 to receiveelectrical energy and convert and store the electrical energy in theform of thermal energy. In some implementations, at least one of theelectrical energy sources 501 may comprise an input energy source havingintermittent availability. However, electrical energy sources 501 mayalso include input energy sources having on-demand availability, andcombinations of intermittent and on-demand sources are also possible andcontemplated. The system 503 can be operatively coupled to a heatrecovery steam generator (HRSG) 509 which is configured to receiveheated air from the system 503 for converting the water flowing throughconduits 507 of the HRSG 509 into steam for the steam turbine 515. In analternative implementation, HRSG 509 is a once-through steam generatorin which the water used to generate steam is not recirculated. However,implementations in which the water used to generate steam is partiallyor fully circulated as shown in FIG. 6 are also possible andcontemplated.

A control unit can control the flow of the heated air (and moregenerally, a fluid) into the HRSG 509, based on load demand, cost perKWH of available energy source, and thermal energy stored in the system.The steam turbine 515 can be operatively coupled to a steam generator509, which can be configured to generate a continuous supply ofelectrical energy. Further, the steam turbine 515 can also release acontinuous flow of relatively lower-pressure 521 steam as output tosupply an industrial process. Accordingly, implementations are possibleand contemplated in which steam is received by the turbine at a firstpressure and is output therefrom at a second, lower pressure, with lowerpressure steam being provided to the industrial process. Examples ofsuch industrial process that may utilize the lower pressure output steaminclude (but are not limited to) production of liquid transportationfuels, including petroleum fuels, biofuel production, production ofdiesel fuels, production of ethanol, grain drying, and so on.

The production of ethanol as a fuel from starch and cellulose involvesaqueous processes including hydrolysis, fermentation and distillation.Ethanol plants have substantial electrical energy demand for processpumps and other equipment, and significant demands for heat to drivehydrolysis, cooking, distillation, dehydrating, and drying the biomassand alcohol streams. It is well known to use conventional electric powerand fuel-fired boilers, or fuel-fired cogeneration of steam and power,to operate the fuel production process. Such energy inputs are asignificant source of CO₂ emissions, in some cases 25% or more of totalCO₂ associated with total agriculture, fuel production, andtransportation of finished fuel. Accordingly, the use of renewableenergy to drive such production processes is of value. Some ethanolplants are located in locations where excellent solar resources areavailable. Others are located in locations where excellent windresources are available.

The use of electrothermal energy storage may provide local benefits insuch locations to grid operators, including switchable electricity loadsto stabilize the grid; and intermittently available grid electricity(e.g. during low-price periods) may provide a low-cost continuous sourceof energy delivered from the electrothermal storage unit.

The use of renewable energy (wind or solar power) as the source ofenergy charging the electrothermal storage may deliver importantreductions in the total. CO₂ emissions involved in producing the fuel,as up to 100% of the driving electricity and driving steam required forplant operations may come from cogeneration of heat and power by a steamturbine powered by steam generated by an electrothermal storage unit.Such emissions reductions are both valuable to the climate andcommercially valuable under programs which create financial value forrenewable and low-carbon fuels.

The electrothermal energy storage unit having air as a heat transferfluid may provide other important benefits to an ethanol productionfacility, notably in the supply of heated dry air to process elementsincluding spent grain drying. One useful combination of heated airoutput and steam output from a single unit is achieved by directing theoutlet stream from the HRSG to the grain dryer. In this manner, a givenamount of energy storage material (e.g. brick) may be cycled through awider change in temperature, enabling the storage of extra energy in agiven mass of storage material. There may be periods where the energystorage material temperature is below the temperature required formaking steam, but the discharge of heated air for drying or otheroperations continues.

In some implementations thermal storage structure 503 may be directlyintegrated to industrial processing systems in order to directly deliverheat to a process without generation of steam or electricity. Forexample, thermal storage structure 503 may be integrated into industrialsystems for manufacturing lime, concrete, petrochemical processing, orany other process that requires the delivery of high temperature air orheat to drive a chemical process. Through integration of thermal storagestructure 503 charged by VRE, the fossil fuel requirements of suchindustrial process may be significantly reduced or possibly eliminated.

The control unit can determine how much steam is to flow through acondenser 519 versus steam output 521, varying both total electricalgeneration and steam production as needed. As a result, the integratedcogeneration system 500 can cogenerate steam and electrical power forone or more industrial applications.

If implemented with an OTSG as shown in FIG. 4 instead of therecirculating HRSG shown in FIG. 6 , the overall integrated cogenerationsystem 500 can be used as thermal storage once-through steam generator(TSOTG) which can be used in oil fields and industries to deliver wetsaturated steam or superheated dry steam at a specific flow rate andsteam quality under automated control. High temperature delivered by thebricks and heating elements of the system 503 can power the integratedheat recovery steam generator (HRSG) 509. A closed air recirculationloop can minimize heat losses and maintain overall steam generationefficiency above 98%.

The HRSG 509 can include a positive displacement (PD) pump 511 undervariable frequency drive (VFD) control to deliver water to the HRSG 509.Automatic control of steam flow rate and steam quality (includingfeed-forward and feed-back quality control) can be provided by the TSOTG500. In an exemplary example implementation, a built-in Local OperatorInterface (LOI) panel operatively coupled to system 500 and the controlunit can provide unit supervision and control. Further, thermal storagestructure 503 can be connected to a supervisory control and dataacquisition system (SCADA)) associated with the steam power plant (orother load system). In one implementation, a second electrical powersource is electrically connected to the steam generator pumps, blowers,instruments, and control unit.

In some implementations, system 500 may be designed to operate usingfeedwater with substantially dissolved solids; accordingly, arecirculating boiler configuration is impractical. Instead, aonce-through steam generation process can be used to deliver wet steamwithout the buildup of mineral contaminants within the boiler. Aserpentine arrangement of conduits 507 in an alternative once-throughconfiguration of the HRSG 509 can be exposed to high-temperature airgenerated by the thermal storage structure 503, in which preheating andevaporation of the feedwater can take place consecutively. Water can beforced through the conduits of HRSG 509 by a boiler feedwater pump,entering the HRSG 509 at the “cold” end. The water can change phasealong the circuit and may exit as wet steam at the “hot” end. In oneimplementation, steam quality is calculated based on the temperature ofair provided by the thermal storage structure 503, and feedwatertemperatures and flow rates, and is measured based on velocityacceleration at the HRSG outlet. Embodiments implementing a separator toseparate steam from water vapor and determine the steam quality based ontheir relative proportions are also possible and contemplated.

In the case of an OTSG implementation, airflow (or other fluid flow) canbe arranged such that the hottest air is nearest to the steam outlet atthe second end of the conduit. An OTSG conduit can be mountedtransversely to the airflow path and arranged in a sequence to providehighly efficient heat transfer and steam generation while achieving alow cost of materials. As a result, other than thermal losses fromenergy storage, steam generation efficiency can reach above 98%. Theprevention of scale formation within the tubing is an important designconsideration in the selection of steam quality and tubing design. Aswater flows through the serpentine conduit, the water first rises intemperature according to the saturation temperature corresponding to thepressure, then begins evaporating (boiling) as flow continues throughheated conduits.

As boiling occurs, volume expansion causes acceleration of the rate offlow, and the concentration of dissolved solids increases proportionallywith the fraction of liquid phase remaining. Maintaining concentrationsbelow precipitation concentration limits is an important considerationto prevent scale formation. Within a bulk flow whose average mineralprecipitation, localized nucleate and film boiling can cause increasedlocal mineral concentrations at the conduit walls. To mitigate thepotential for scale formation arising from such localized increases inmineral concentration, conduits which carry water being heated may berearranged such that the highest temperature heating air flows acrossconduits which carry water at a lower steam quality, and that heatingair at a lower temperature flows across the conduits which carry thehighest steam quality flow.

Returning to FIG. 6 , various implementations are contemplated in whicha fluid movement device moves fluid across a thermal storage medium, toheat the fluid, and subsequently to an HRSG such as HRSG 509 for use inthe generation of steam. In one implementation, the fluid is air.Accordingly, air circulation through the HRSG 509 can be forced by avariable-speed blower, which serves as the fluid movement device in suchan embodiment. Air temperature can be adjusted by recirculation/mixing,to provide inlet air temperature that does not vary with the state ofcharge of the bricks or other mechanisms used to implement a thermalstorage unit. The HRSG 509 can be fluidically coupled to a steam turbinegenerator 515, which upon receiving the steam from the HRSG 509, causesthe production of electrical energy using generator 517. Further, thesteam gas turbine 515 in various embodiments releases low-pressure steamthat is condensed to a liquid by a condenser 519, and then de-aeratedusing a deaerator 513, and again delivered to the HRSG 509.

An exemplary configuration specification of one implementation of acogeneration system using an OTSG for steam generation is providedbelow.

Parameter Value Nominal Steam Delivery 5,000 barrels per day SteamQuality (nominal) 80%; (60%-96%) Max Charging Rate 70 MW Energy Storage350 MWh Energy Output from Storage 15 hours at max rate Storage LossRate 1% per day Outlet Pressure 900 to 2200 psig (per spec) InletPressure 50 psig (PD pump) or per spec Running Power Per outletpressure, up to 450 kW Dimensions 35 × 60 ft (11 × 18 m) InstallationOutdoor

Referring to FIG. 89 , in some example implementations, an integratedcogeneration system 500 as shown in FIG. 6 is coupled to a fuel-poweredgenerator to provide a thermal storage integrated combined cycle plant550 for efficient and reliable operation of a steam power plant. Acombined cycle power plant may include a gas powerplant including acompressor 502 that mixes air into a fuel stream. The fuel and airmixture are then burnt in an expansion turbine 516 to generatepressurized exhaust, which is provided to a generator 518 to produceelectrical energy. Further, the combined cycle plant may transfer theexhaust gas to a heat recovery steam generator (HRSG) 509. The HRSG 509may include a positive displacement (PD) pump 511 under variablefrequency drive (VFD) control to deliver water to the HRSG 509. Whenoperating as part of a fuel-powered cycle, HRSG 509 uses the thermalenergy of the exhaust gas from turbine 516 to convert the water intosteam. Output of the HRSG 509 can be operatively coupled to a steamturbine generator 515, which upon receiving the steam from the HRSG 509,produces electrical energy using generator 517.

Further, the steam gas turbine 515 releases low-pressure steam that iscondensed to a liquid by a condenser 519, and then de-aerated using adeaerator 513, and again delivered to the HRSG 509. For example, asshown in the expanded view, the steam turbine generator 515 receiveshigh pressure steam from the HRSG 509. At a first turbine 515A that ispowered by the high pressure steam, intermediate pressure steam isoutput to the deaerator 513, which may remove the oxygen from the steam,and provide as its output liquid fluid to the input of the HRSG 509 viaPD pump 511. An output of the first turbine 515A may be low pressuresteam, which is provided to an industrial process. A second turbine 515Bthat is powered by the remaining pressurized steam also generateselectricity, and provides low pressure steam as its output to acondenser. An output of the condenser may be warm air, which may be usedfor an industrial process, such as grain drying or the like.

The thermal storage integrated combined cycle plant 550 can include thethermal energy storage structure 503 being fluidically coupled to theHRSG 509 of the combined cycle power plant. In one implementation, theheated air (at a predefined temperature) for the HRSG is provided by thethermal storage structure 503 alone or in combination with the exhaustemitted by the gas turbine 516. A control unit can control the flow ofany combination of the heated air (from thermal storage structure 503)and exhaust gas by the gas turbine 516 into the HRSG 509, based on, forexample, factors including load demand, availability and cost per KWH ofavailable energy sources, cost per KWH for the operation of the combinedcycle power plant, and thermal energy stored in the thermal storagestructure 503.

In other example implementations, thermal storage structure 503 and acoal power plant may be integrated with a steam power plant through theHRSG 509 to provide another example implementation of a thermal storageintegrated combined cycle plant for efficient and reliable operation ofa steam power plant. The heated air-being provided by thermal storagestructure 503, alone or in combination with the exhaust emitted by thecoal power plant can be supplied to the HRSG 509 for converting thewater into steam for the steam turbine. A control unit may control theflow of any combination of the heated air (from the thermal storagestructure) and exhaust gas by the coal power plant into the HRSG, basedon, for example, factors including load demand, availability and costper KWH of an available energy source, cost per KWH for the operation ofthe coal power plant, and thermal energy stored in the thermal storagestructure.

Referring to FIG. 90 , an integrated cogeneration system capable ofdelivering high-pressure steam as well as electric power may beconfigured as shown in one implementation. A thermal storage structure400 as described in FIG. 4 may be configured with an integrated HRSGthat delivers high-pressure, optionally superheated steam that flowsthrough a steam turbine 602 that drives an electric generator 604, whichmay be electrically coupled to local electrical loads or an electricalgrid 606 to maintain and/or provide a continuous supply of electricalpower at a load. All or a portion of the exhaust steam from the steamturbine may flow through a heat exchanger 610 which cools the steam intocondensate which is returned for reheating by pump 611. The heatexchanger 610 transfers the heat into a flow of water 612 which isdirected through another HRSG 613 in thermal storage structure 608,which provides steam for an industrial process. The heat transferred byheat exchanger 610 increases the steam production by HRSG 613 bypreheating the inlet water. This accomplishes high-efficiencycogeneration of electric power and process steam, even when the requiredsteam is at high temperatures and pressures, by capturinglow-temperature thermal energy from the waste steam of turbine 602 intothe feedwater of HRSG 613.

Referring to FIG. 87 as discussed above, in some implementations athermal energy storage system may be used to power the production ofhydrogen and/or hydrocarbon fuels by delivering both heat and power todrive a high-temperature solid-oxide electrolyzer. Solid-oxideelectrolyzers can reduce the electrical energy input needed per unit ofhydrogen by harnessing thermal energy to drive the breaking of chemicalbonds. Relatively higher total efficiency may be achieved by directing aportion 4101 of the high-temperature stored heat from VRE ashigh-temperature heat to an electrolyzer 4102 which is also fully orpartially powered by electricity 4103 generated by a thermal generationprocess 4104, such as a Rankine cycle or supercritical CO₂ cycle. Insome implementations, electrolyzer 4102 may co-electrolyze water andCO₂, or separate electrolyzers may electrolyze water and CO₂, with allor a portion of the resulting syngas directed to a methanation orFischer-Tropsch type conversion unit 4105 so as to make a syntheticgaseous or liquid hydrocarbon fuel.

In one implementation, stored VRE and an HRSG are coupled to anindustrial process facility in such a manner as to eliminate gascombustion in auxiliary, emergency, or backup boilers. Referring to FIG.91 , an industrial process plant such as a refinery, petrochemicalplant, or other process plant 91600 may have one or more steamdistribution networks 91601 that provide steam to process units such aspumps 91604, blowers 91605, process reactors 91606, turbines 91607, orother uses. In one implementation, the continuous operation of the steamnetwork is required for the safe operation of the plant, includingduring startup and shutdown operations.

Some industrial process units 91602, principally those with exothermicreactions, may generate all or a portion of the steam 91603 in thenetwork during normal operation. In some implementations, however, forthe safe and effective operation of the plant other sources of steammust be instantly available in the event of the shutdown of one suchunit 91602. In some prior implementations gas-fired or oil-fired boilers91611 have been used. In some implementations such equipment must bemaintained at operating temperature continuously in order to be able toimmediately increase its firing rate to provide the steam necessary insuch a shutdown event. Such units may employ a conventionalrecirculating design with a steam drum 91613 which is open to the mainsteam network, and the heat necessary to keep the drum warm may beprovided by excess steam produced by the process units 91602. However,the firebox or burner portion of the boiler must also be kept warm insome implementations, and this is commonly done by operating the burner91612 continuously at a low firing rate. This is a source of continuousCO₂ and other pollutants.

In the depicted implementation of a thermal energy storage system, thethermal storage unit 91608 has an HRSG with recirculating drum boilerprocess 91609, where the drum is again open to the steam header 91601and the HRSG section is kept warm by excess steam. The thermal storageunit may maintain its temperature via its insulation, with low energylosses. The storage unit may be charged by a directly-connected VREsource, or may be rapidly or slowly charged from an electricity grid ora local power generation source, in such a manner as to minimize energycost. The storage unit is configured to instantly (within seconds) beginhigh-rate steam production from storage, and operate until storagecapacity is exhausted. In this implementation the fuel-fired boiler91611 may be left in a “cold storage” configuration, burning no fuel,until a shutdown requires its operation. The operating time of thethermal storage unit provides an extended time period to properly startand warm up the fuel-fired boiler before placing it into service foroutages that extend beyond the discharge period of the storage unit.

Other Energy Usage Applications

FIG. 92 is a schematic illustration 10000 that shows the availability ofelectricity from a solid oxide generation facility on a typical day. Theillustration shows potential uses for available electric power. In oneimplementation, use 1 is the local consumption of relatively high-priceelectricity used at the industrial facility itself. As power productionfrom a solar facility begins in early morning, the electricity issupplied to that highest value use first as the available solarelectricity production rises.

More specifically, the time of operation or charging may be controlledin such a manner as to optimize other economic value, such as the supplyof electricity to a grid at periods of high price or high value. Curve10001 represents available energy during a solar day between thebeginning of the solar day and the end of the solar day. While the timesof 5 AM and 8 PM are shown by way of example, it is understood that thetime will vary, depending on the location and time of year.

Curve 10001 shows the solar energy increasing from the beginning of thesolar day to a maximum level and then decreasing towards the end of thesolar day. Within the available solar energy, the chart illustrates thatthere may be multiple uses of the solar energy.

As shown in the additional charts, a first use 1 and a second use 2, asexplained above, are shown. Additionally, outside factors 3, such asgrid storage, capacity, energy supply, pricing variations due to energymarkets or the like may influence the availability and demand of thesolar energy for charging the thermal energy storage system. A controlsystem, as described above, may incorporate these factors intodeterminations and recommendations to the operator regarding theoperation of the thermal energy storage system, such as the charging anddischarging of the stacks. Accordingly, the thermal energy storagesystem may dispatch energy for multiple purposes or uses from the outputof the thermal energy storage system, while taking into account thesefactors.

As shown in the first additional chart at scenario 10007, less solarenergy may be available for the thermal energy storage system later inthe solar day. Alternatively, as shown in the second additional chart at10009, less solar energy may be available for charging the thermalenergy storage system during the early portion and the middle to laterportion of the day. Other variations may exist, as would be understoodby those skilled in the art.

For example, use 1 (represented by region 10005) may be a local electricload in one implementation. This may represent the electricity providedto a local area by a photovoltaic array. Additionally, other uses suchas use 2 (represented by region 10003) may also use the available solarenergy. As indicated by the shaded region, the remaining solar energy isavailable to charge a thermal energy storage system connect to the solarenergy source exhibiting the energy profile of curve 10001.

In one implementation, use 2 is a second-high value use, which may beand industrial process such as electrolysis. Use 2 is then fully poweredfor as long as possible while excess energy beyond that needed for use 1is available. As electricity production rises further later in the day,electricity is available for other purposes, including charging athermal energy storage device, and/or participating in the supply ofelectricity, for example, to an electricity grid, where electricity maybe valued at very different prices at different times. This system maybe operated in such a way that, for example, electric power to a thermalstorage unit may be turned off and electric power instead released tothe grid as desired based upon demand, pricing or other factors, and/orpower may be brought from the grid to power a storage unit or for one ofother possible uses depending upon local grid conditions.

Self-Sufficient Off Grid Infrastructure

In some implementations, use of high voltage DC/DC conversion allows forvery high efficiency connection of solar fields with suitable distanceto loads such as a thermal energy storage unit that can be coupled toelectrolyzers and used for electric vehicle charging. Further, a thermalenergy storage system may have integrated hydrogen production in someimplementations, with electric power generation from hydrogen and alsohave integration of lithium-ion batteries. A thermal energy storagesystem can also be coupled to drive desalination to produce a completelyoff-grid facility or military base that is self-powering for itsdomestic loads, its heat loads and its vehicles.

Refiring of Steam Plants

Since outlet temperatures from a thermal energy storage unit are higherthan gas turbine outlet temperatures in some implementations, outletfrom a thermal storage structure can fire the same HRSGs as a gasturbine, potentially cutting the storage unit cost by about, e.g., 40%.In some implementations, nearly all the off-specification operation ofthermal plants can be reduced or eliminated by coupling to a thermalstorage unit as disclosed herein. Combined cycle gas turbine (CCGT)plants were designed to run at nominal output at high capacity factor,but may not be operated in this way if connected to a power grid withvariable load. In California, for example, such plants may spendsignificant time as “spinning reserve”—running at idle so as to be ableto respond to load changes. CCGT plants may also do daily start-stopoperation requiring warmup of all components to bring the plant toready-to-operate condition and spend significant time in a“load-following” mode of throttling generation in response to load. Suchreserve and warmup operations are approximately 0% fuel efficient, andthere is tension between fuel cost (dictating warming the plant as fastas possible) and operations and maintenance (O&M) cost (dictatingwarming the plant slowly to cause less stress damage). Thisload-following operation in CCGT plants results in efficiency losses ofat least 5% and sometimes 15%.

Integrating thermal energy storage systems such as those in the exampleimplementations disclosed herein with thermal plants may address theefficiency problems describe above. About, e.g., 90% of a plant's warmupprocess can be powered by intermittent renewable generation stored in athermal storage unit. HRSG and steam turbine (ST) preheat energy is asignificant factor in many plants. A “part spinning reserve”configuration can be achieved where a thermal energy storage unit fullypowers the operating steam turbine, from idle to full power, so theplant can respond instantly with up to about, e.g., 40% of nominaloutput running completely zero-carbon, and can add then add the gasturbine (GT) in around 10 minutes.

Thermoelectrochemical Converters

Thermoelectrochemical converters are solid-state devices that utilizethe electrochemical potential of a gas pressure applied throughout amembrane electrode assembly to convert heat into electricity via gascompression and expansion. A thermoelectrochemical converter thatutilizes the electrochemical potential of a hydrogen pressuredifferential applied across a proton conductive membrane is known. Thesystem consists of two membrane electrode assemblies (MEA) to convertheat into electricity via hydrogen compression and expansion. One stackis operated at a relatively low temperature and coupled to a heat sink,and the other stack is operated at a relatively high temperature andcoupled to a heat source. Hydrogen gas circulates in a closed system.The net electrical power or voltage that can be achieved increases asthe temperature differential between the two MEA stacks increases.

Thermophotovoltaic (TPV) Cogeneration

Thermophotovoltaic (TPV) energy conversion is a process of convertingthermal radiation to electricity directly and includes a thermal emitterand a photovoltaic diode cell. The temperature of the thermal emitterneeded varies based on system but typically ranges from about 900° C. toabout 1300° C., e.g., 900° C. to 1300° C. At these TPV temperatures,radiation is radiated mostly in the form of near infrared and infraredfrequencies. The photovoltaic diodes absorb some of the radiation andconverts them into electricity. In art, a thermophotovoltaic cellwith >29% power conversion efficiency was achieved, at an emittertemperature of 1207 C with potential for further efficiency improvement.Such a TPV system may allow for efficient cogeneration for heat andelectricity.

The thermal emitter may be, for example, a graphite heated by resistiveheating and operated with an inert atmosphere to prevent the oxidationof graphite. Indium gallium arsenide (InGaAs) or silicon (Si) type PVcells can be used for example to generate electricity.

The high temperature thermal storage system disclosed herein can beeffectively coupled with a thermophotovoltaic cogeneration, offeringbenefits including but not limited to the following:

The high temperatures combined with the storage technology matches wellwith high efficiency TPV systems which utilize thermal radiation togenerate electricity

Unlike other thermal storage systems relying largely on convective heattransfer, the “radiative echo chamber” concept described herein can workin concert with convective heat transfer to get radiation out of thethermal storage assembly or array. In one implementation, the arraysinclude relatively inexpensive materials with mediocre thermal transfermedium to keep costs low. The radiation chambers in effect increase thesurface area from which energy can be extracted, allowing for fasterdischarge rates without rapidly degrading top temperatures.

Extremely high storage temperatures above 2000° C. are practicallyachievable with a thermal storage system of the kind described herein.Such temperatures allow for the use of lower cost, more available buthigher bandgap cells using silicon semiconductors for TPV.

Inert gas compatible with the emitter (e.g. graphite) and TPV system canbe used directly as the heat exchange fluid in the thermal storagesystem decreasing complexity and cost.

An optional feature may include movable shields or other means to shieldor block the incoming radiation at the TPV cells during the time thatthe thermal storage system is being charged. This allows the cells toremain cool, reduce the design cooling load and extend cell lifetime.During periods when the thermal storage system is being heatedelectrically coincides with periods of low cost or abundant electricalsupply, making TPV operation unnecessary.

In one example implementation, the lower temperature heat arising fromcooling during charging and then during power generation is used foranother purpose, such as steam generation, water preheating,supercritical CO₂ heating for power generation or for industrial processheat. This heat can be blended with hotter air coming from the storagecore or segregated (e.g., introduced into another heat exchanger whiche.g., supplies preheat for a process that also employs high-temperatureheat, or used for another process). This would further increase thetotal efficiency of energy use for a combined heat and powerapplication, examples of which are disclosed in other parts of thisapplication, such as cement and glass production.

The combination of high temperature thermal storage and TPV describedherein could unlock significant value even in a pure electric powerstorage application. TPV can be used as a “topping” cycle and steamturbine as a “bottoming” cycle, resulting in highelectricity-to-electricity efficiencies approaching 50%. The TPVcomponent could provide “instant” services including load following,frequency and voltage regulation with rapid (e.g. millisecond) responsetimes. The combined thermal storage-TPV system would function similarlyto a lithium ion battery for part of the electric power output,providing grid stability value, with an added benefit of a long-termstorage unit at a significantly lower cost and size.

Thermoelectrochemical Converters Run by High Temperature Thermal StorageSystem

As described above, the net efficiency of a thermoelectrochemical systemcan be increased by increasing the temperature differential between thetwo membrane electrode assemblies (MEA). Implementations of a thermalenergy storage system disclosed herein can be coupled to the hot end ofa thermoelectrochemical converter to provide near constant or constanthigh temperature heat. In the present example implementation, a heatexchanger in the high temperature outlet of the thermal storage systemis coupled to the high temperature MEA in the thermoelectrochemicalconversion system, at temperatures between 500° C. and 1200° C. Theremaining heat may be used to generate steam in a Heat Recovery SteamGenerator, for example, or used for another industrial application. Inanother example implementation, the high temperature portion of thethermoelectrochemical converter may be coupled to the heated gas fromthe secondary heat outlet (i.e. from cooling the high temperature energysources) to generate electricity while the primary heat outlet (i.e.,the highest temperatures, for example, at 1600° C.) is used forindustrial applications such as power generation or cement production.Such cogeneration of heat and power could have combined efficiency ofnearly 90% because waste heat from the thermoelectrochemical electricgeneration can be used for industrial purposes.

In some example implementations, the environment is used as the heatsink. In other example implementations, the cool side of thethermoelectrochemical converter could use the feedwater to the HRSG asthe heat sink, raising the temperature of the feedwater, recovering thatenergy for steam generation useful for a steam power cycle or industrialprocesses. Preheating of thermal exchange fluid in this way can beapplied to other processes, including, for example, the cementproduction process. A cooled stream of CO₂ may first be used as the heatsink for the thermoelectrochemical converter, raising the temperature ofCO₂, when is then heated to operational temperatures of the cement kiln,preheater or precalciner. The heat/power balance allows retention ofvery high efficiency of heat and power cogeneration with hightemperature heat loads for industrial processes.

Electric Booster

FIG. 93 shows an example implementation 9300 of the thermal energystorage system that includes an electric booster 9307 that is configuredto boost the temperature of a fluid output to meet a requirement of anend use. In this example, electricity is provided from a source 9301,such as an off-grid solar array or other VRE, to first and secondthermal storage units 9303, 9305, referred to here as heat batteries.The electricity may be provided as DC current or AC current.

While the energy source 9301 is shown as an off-grid renewable source ofenergy, and more specifically, solar photovoltaic cells, other renewablesources could be used in substitution or combination, such as wind.Further, grid electricity 9302 could be used in substitution orcombination with the off-grid source of electricity. The electricityfrom the energy source 9301 is used to provide the electrical energy asinputs to the first and second heat batteries 9303 and 9305, as well asfor the electric booster 9307. The first and TSUs 9303 and 9305 caninclude single stacks, double stacks or more, or some combination; theTSU's 9303 and 9305 do not have to contain the same number of stacks. Inone embodiment, either or both of the TSUs 9303 and 9305 can include sixstacks.

The first heat battery 9303 can be configured to store electricity asheat, to provide heated fluid as an input to an HRSG, or to providesteam to a steam turbine 9309. Alternatively, an OTSG may be usedinstead of the HRSG.

The second heat battery 9305 provides hot fluid as an output for use inan industrial application, such as in a cement kiln or steel production,referred to here as a process load 9311, also referred to as a dryingload. It may be the heat battery 9305 provides the fluid at atemperature of 1000° C., which is below the drying load requirement,which for a given application may be much higher, such as 1300° C.

Different fluids may be used in the first and second heat batteries9303, 9305. For example, air may be used as the fluid for the first heatbattery 9303 to power the steam turbine 9309, while CO₂ is used as thefluid for the second heat battery 9305, as needed for a particularindustrial process. For example, in the case of the industrial processbeing a calciner, a closed loop is provided in which the fluid isrecaptured for input to the heat battery 9305. The temperature of thereturn air is such that the air does not require preheating. In otherindustrial applications, an open loop may be provided, such thatatmospheric air 9315 is preheated by the condenser 9313.

To raise the temperature of the heated fluid to the drying loadrequirement, the electric booster 9307 is provided at the discharge ofthe hot fluid. Accordingly, hot fluid output from the second heatbattery 9305 passes through the booster heater 9307, and then to theprocess load 9311, at the required temperature for the industrialprocess.

In the second heat battery 9305, the fluid may be air, CO₂, or otherfluid, depending on the industrial application at an output temperature,such as 1000° C.-1100° C. Further, the byproduct fluid of the industrialprocess may be recirculated as the input fluid to the heat battery 9305,depending on the industrial process.

The electric booster 9307 may be an electric resistance heater thatboosts the fluid temperature from the maximum output of the heat battery9305 to the temperature required by the process load 9311. Example ofthe types of industrial applications that would require high temperaturefluid input for the process load 9311 include calcining, steelproduction, ethylene production, and steam methane reforming ofhydrogen. The electric booster 9307 may be an industrial electricfurnace, and may optionally include fins or other structures to transferelectrical resistance heat to the air. The heaters of the electricbooster may be metallic (e.g., resistive coil), ceramic or other knownmaterials. The stream of fluid output from the first heat battery 9305is heated by direct contact with the heaters of the electric booster9307.

When the energy source 9301 is available, it may provide the electricityfor the electric booster 9307, as shown in FIG. 93 by the output linefrom source 9301 to the booster 9307. For example, the solar array canprovide power to the booster heater when solar energy is available.Alternatively, when solar energy is not available, or available only inlimited quantity, the steam turbine 9309 provides all or a needed,supplemental portion of the electricity to the electric booster 9307.

The byproduct fluid from the steam turbine may be cooled by passingthrough a condenser 9313, such as a cooling tower, before beingcondensed to a liquid state, and provided as an input to the steamgenerator of the heat battery 9303. Optionally, the condenser 9313 mayserve as a preheater to heat incoming air 9315, for use as the input tothe second heat battery 9305. In other words, the condenser 9313 is aheat exchanger that transfers heat from the byproduct fluid (e.g.,low-pressure steam) from the steam turbine 9309 to the input fluid 9315.As a result, the input fluid to the heat battery 9305 is preheated.

While FIG. 93 illustrates separate first and second heat batteries 9303and 9305, a single heat battery could instead be used. For example, hotair fluid could be streamed off and diverted from a single heat batterywith multiple stacks, such that some portion of the hot fluid isprovided to the process and the remainder of the hot fluid is providedto a steam generator. Such an approach might be used when the heatbattery is charged from the grid, and economically optimized such thatthe heat battery charging is carried out at a time of low electricityprices, e.g., below some predetermined price, and the same electricityis provided to the electric booster. According to this approach, thesteam turbine 9309 is used as a backup, on an as-needed basis.

3. Advantages Over Prior Systems

Stored high-temperature energy introduced as heated air into biomasscombustion and gasification processes can make substantial contributionsto the effective and safe operation of such facilities. This may causevarious improvements in air emissions associated both with oxides ofnitrogen and unburned fuel, ability to handle biomass fuels that arewetter during certain times, as well as improvements in plantreliability and capacity factor, particularly during periods ofuncertain or limited biomass supply, reductions in corrosion due toshifts in operating point, ability to operate the plant during periodsof limited or no fuel ability, ability to operate the plant as an energystorage facility.

Various Cogeneration Implementations

Thus, in accordance with the above, a number of cogeneration systemimplementations are possible and contemplated, a number of examples ofwhich are now provided.

In one implementation, a cogeneration apparatus includes a thermalstorage assemblage 4100) including a plurality of thermal storageblocks, wherein at least some of the thermal storage blocks includemultiple radiation cavities and multiple fluid flow slots, wherein someof the radiation cavities and some of the fluid flow slots areconfigured to define fluid pathways through the thermal storage blocks.The cogeneration apparatus further includes a plurality of heaterelements positioned within the thermal storage assemblage and adjacentto at least some of the radiation cavities, wherein each of theplurality of heater elements is configured to heat at least one of thethermal storage blocks via energy radiated into multiple ones of theradiation cavities and onto surfaces that bound the respective radiationcavities. A fluid movement system is configured to direct a stream offluid through the fluid pathways to heat the fluid to a specifiedtemperature range, wherein the fluid movement device is configured toprovide the heated fluid in the specified temperature range to a solidoxide electrolysis system configured to extract hydrogen from water andoutput the heated fluid at a lower temperature. A steam generatorconfigured to receive the lower temperature fluid from the electrolysissystem convert input feed water into steam. In various implementations,the steam generator is a once-through steam generator, and may also be aheat recovery steam generator. The steam generator includes a pluralityof conduits coupled to receive the input feed water, wherein selectedones of the conduits are arranged to mitigate scale formation andoverheating. In certain implementations, ones of the plurality ofconduits are arranged in the steam generator transversely to a path offlow of the lower temperature fluid. The thermal storage assemblycomprises an enclosure containing the plurality of thermal storageblocks and a thermal barrier separating a first subset of the pluralityof thermal storage blocks from a second subset of the plurality ofthermal storage blocks. The fluid movement system is configured todirect the stream of fluid through the fluid pathways of one of thefirst and second subsets of thermal concurrent with an electricitysource adding heat to another one of the first and second subset. Insome implementations, the fluid comprises oxygen and nitrogen. Varioussources of electricity may be used to charge the thermal storageassemblage. In one implementation, the thermal storage assemblage isconfigured to store thermal energy generated by a conversion of inputelectricity from an first input energy supply, the first input energysupply having intermittent availability. Implementations are furthercontemplated in which the thermal storage assemblage is furtherconfigured to store thermal energy generated by a conversion of inputelectricity from an second input energy supply configured to provideelectricity on demand.

In yet another implementation, a cogeneration apparatus includes athermal storage assemblage having a plurality of thermal storage blocks,wherein at least some of the thermal storage blocks include multipleradiation cavities and multiple fluid flow slots, wherein some of theradiation cavities and some of the fluid flow slots are configured todefine fluid pathways through the thermal storage blocks. Theimplementation further includes a plurality of heater elementspositioned within the thermal storage assemblage and adjacent to atleast some of the radiation cavities, wherein each of the plurality ofheater elements is configured to heat at least one of the thermalstorage blocks via energy radiated into multiple ones of the radiationcavities and onto surfaces that bound the respective radiation cavities.A fluid movement system is configured to direct a stream of fluidthrough the fluid pathways to heat the fluid to a specified temperaturerange. A steam generator is configured to receive the fluid to convertinput feed water into input steam having a first pressure. A steamturbine configured to receive the input steam and provide output steamat a second pressure that is less than the first pressure. Suchimplementations may further include a second fluid movement deviceconfigured to move the output steam to an industrial plant for use in anindustrial process.

The steam generator, in various implementations, is a once-through steamgenerator. The steam generator includes a plurality of conduits coupledto receive the input feed water, wherein selected ones of the conduitsare arranged to mitigate scale formation and overheating. Ones of theplurality of conduits are arranged in the steam generator transverselyto a path of flow of the lower temperature fluid.

With regard to the industrial process, a number of different processesare possible and contemplated. In one implementation, the industrialprocess comprises producing petroleum-based fuels. In anotherimplementation, wherein the industrial process comprises producingbiofuels. In yet another implementation, the industrial processcomprises producing diesel fuels. In still a further implementation, theindustrial process comprises drying grains. These industrial processesare provided here as examples, and do not constitute an exhaustive listof possible industrial processes that may be used with the variousimplementations. The present disclosure contemplates a wide variety ofindustrial processes beyond the examples given here. It is further notedthat implementations are possible and contemplated wherein the steamturbine is configured to cause an electrical generator to provideelectricity to the industrial process.

In yet another possible implementation, a cogeneration apparatusincludes a thermal storage assemblage having a plurality of thermalstorage blocks, wherein at least some of the thermal storage blocksinclude multiple radiation cavities and multiple fluid flow slots,wherein some of the radiation cavities and some of the fluid flow slotsare configured to define fluid pathways through the thermal storageblocks. A plurality of heater elements is positioned within the thermalstorage assemblage and adjacent to at least some of the radiationcavities, wherein each of the plurality of heater elements is configuredto heat at least one of the thermal storage blocks via energy radiatedinto multiple ones of the radiation cavities and onto surfaces thatbound the respective radiation cavities. A fluid movement system isconfigured to direct a stream of a first fluid through the fluidpathways to heat the first fluid to a specified temperature range. Afirst steam generator is configured to, using the first fluid, convertinput feed water into steam. A steam turbine configured to causegeneration of electricity using the steam. The implementation alsoincludes a preheater configured to, using waste heat from the steamturbine, preheat feed water provided to a second steam generator.

In an implementation, the first steam generator is a heat recovery steamgenerator, and may also be (or alternatively be) a once-through steamgenerator. Various implementations also include a condenser coupled tothe steam turbine, wherein the condenser is configured to condense steamreceived from the steam turbine into water a recirculation pumpconfigured to provide, as feed water to the first steam generator, waterproduced by the condenser. The second steam generator in variousimplementations is configured to generate steam using a second fluidfrom a second storage medium configured to store thermal energy. Thepreheater in various implementations is configured to output a thirdfluid to the thermal storage assemblage.

A further implementation of a cogeneration apparatus includes a thermalstorage assemblage) including a plurality of thermal storage blocks,wherein at least some of the thermal storage blocks include multipleradiation cavities and multiple fluid flow slots, wherein some of theradiation cavities and some of the fluid flow slots are configured todefine fluid pathways through the thermal storage blocks. A plurality ofheater elements is positioned within the thermal storage assemblage andadjacent to at least some of the radiation cavities, wherein each of theplurality of heater elements is configured to heat at least one of thethermal storage blocks via energy radiated into multiple ones of theradiation cavities and onto surfaces that bound the respective radiationcavities. A fluid movement system is configured to direct a stream offluid through the fluid pathways to heat the fluid to a specifiedtemperature range. A steam generator is configured to receive the fluidto convert input feed water into input steam. Various implementationsalso include a measurement unit configured to determine a measured steamquality value of steam output from the steam generator. A controller isconfigured to cause the cause the fluid movement system to direct thestream of fluid, and further configured to use the measured steamquality as feedback to adjust a flow rate of the fluid to maintain themeasured steam quality within a specified steam quality range.

In some implementations, the measurement unit includes a separatorconfigured to separate steam output from the steam generator from watervapor output from the steam generator, wherein the measurement unit isconfigured to determine the measured steam quality based on fraction ofthe water vapor output from the steam generator relative to the steamoutput from the steam generator. Implementations are further possibleand contemplated in which the measurement unit is configured todetermine the steam quality based on a flow velocity of steam outputfrom the steam generator and a mass flow rate of the input feed water.With regard to the steam generator, implementations are possible andcontemplated in which the steam generator is a once-through steamgenerator. The controller of such implementations may be configured tocause delivery of steam in accordance within a specified range of steamdelivery rates. Accordingly, the controller is configured to specify therange of steam delivery rates based on forecast information. Varioustypes of forecast information are possible and contemplated as a basisfor the controller to specify the range of steam delivery rates. Invarious implementations, the forecast information includes weatherforecast information. Implementations in which the forecast informationincludes expected electricity rates are also possible and contemplated.Similarly, implementations in which the forecast information includesexpected steam demand are contemplated. It is noted that the controllermay use one or more types of the forecast information mentioned here,while other types of forecast information not explicitly discussedherein may also be used in various implementations.

In still another implementation, a cogeneration system includes astorage medium configured to store thermal energy generated by aconversion of input electricity from an input energy supply, the inputenergy supply having intermittent availability. A fluid movement deviceis configured to move fluid through the storage medium to heat the fluidto a specified temperature, the fluid comprising oxygen and nitrogen,wherein the fluid movement device is configured to provide the fluid atthe specified temperature to a solid oxide cell electrolysis system thatconverts water to hydrogen and enriches the fluid with oxygen. Suchimplementations may also include a once-through steam generatorconfigured to, using the fluid received from the electrolysis systemconvert input feed water into steam.

These implementations may further include a steam turbine configured tocause an electrical generator to generate of electricity using steamreceived from the steam generator. With regard to thermal storage, thethermal storage unit may comprise a plurality of bricks. A controller inan implementation is configured to cause the fluid movement device tomove fluid at a particular rate. Further contemplated in variousimplementations is a measurement unit configured to measure a parameterof steam output from the steam generator. The controller is configuredto adjust the particular rate based on the measurement of the parameterof steam output. Meanwhile, the measurement unit in variousimplementations comprises a separator configured to measure a quality ofthe steam output from the steam generator by separating the steam into aliquid phase and a vapor phase. Alternatively, implementations in whichthe measurement unit is configured to measure a velocity of steam outputfrom the steam generator are also possible and contemplated. Thecontroller is configured to control an amount of fluid moved through thestorage medium based on a weather forecast. The controller may also beconfigured to control and amount of fluid moved through the storagemedium based on an expected difference in electricity costs on a firstday and a second day.

Various types of electrical sources may comprise the intermittent energysupply in various implementations. In one implementation, theintermittent energy supply comprises a thermophotovoltaic generationsystem configured to convert thermal radiation into electrical energy.The intermittent energy supply may also, or alternatively, comprise awind turbine configured to generate electricity. The intermittent energysupply may also a solar energy source configured to convert solar energyinto electricity, which may be used singularly or with various ones ofthe other types mentioned herein.

The fluid movement device in one implementation comprises a closed fluidrecirculation loop. Implementations may a pump, and wherein the pump isconfigured to force the input feed water through one or more conduits ofthe steam generator. With regard to the steam generator, one or moreconduits may be provided in which feed water flows. In suchimplementations, the one or more conduits may be mounted in the steamgenerator transversely to a path fluid flow.

In yet another implementation, a cogeneration system include a storagemedium configured to store thermal energy generated by a conversion ofinput electricity from an input energy supply, the first input energysupply having intermittent availability. A first fluid movement deviceis configured to move fluid through the storage medium to heat the fluidto a specified temperature. A once-through steam generator is configuredto, using the fluid, convert input feed water into an input steam havinga first pressure. The system may include a steam turbine configured toprovide an output steam at a second pressure that is less than the firstpressure. A second fluid movement device may in various implementationsis configured to move the output steam to an industrial plant for use inan industrial process.

The steam turbine in various implementations is configured to causegeneration of electricity by an electrical generator. The electricalgenerator is configured in some implementations to provide electricityto a power grid.

Various types of industrial processes are possible and contemplated inaccordance with the above. In one implementation, the industrial processcomprises production of biofuels. In another implementation, theindustrial process comprises production of petroleum-based fuels. In yetanother implementation, the industrial process comprises production ofdiesel fuels. Implementations in which the industrial process comprisesdrying of grains are also possible and contemplated. The disclosurecontemplates industrial processes other than those measured here thatmay also benefit from use of an implementation of the cogenerationsystem/apparatus per this disclosure.

The cogeneration system in various implementations includes a controllerconfigured to cause the steam generator to generate steam at a specifiedsteam quality based on steam quality. The steam quality may becalculated by a comprising a measurement unit configured to determinethe steam quality based on separation of steam and water vapor outputfrom the steam generator. In another implementation, the steam qualitymay be calculated by a measurement unit configured to determine thesteam quality based on measurements of steam outlet flow and feed waterinput flow. The steam quality may, in various implementations, beaffected by the rate at which fluid is moved through the storage device.Accordingly, implementations are possible an contemplated in which thecontroller is configured to control a rate at which fluid is movedthrough the storage medium by the first fluid movement device. In someimplementations, the storage medium comprises a plurality of bricks.

Yet another implementation of a cogeneration system includes a firststorage medium configured to store thermal energy generated by aconversion of input electricity from an input energy supply, the inputenergy supply having intermittent availability. The system furtherincludes a fluid movement device configured to move fluid through thestorage medium to heat the fluid to a specified temperature. A firststeam generator is configured to, using the fluid, convert first inputfeed water into steam. A steam turbine is configured to, using thesteam, cause an electrical generator to generate electricity.Implementations may further include a preheater configured to, usingwaste heat from the steam turbine, preheat second feed water provided toa second steam generator.

The steam generator in one implementation is a once-through steamgenerator. However, implementations in which the steam generatorperforms at least some recirculation of feed water are also possible andcontemplated. Accordingly, some implementations include a condenserconfigured to receive at least a portion of the steam from the steamturbine and configured to condense the portion of steam into third feedwater, while a recirculation pump is configured to provide the thirdfeed water to the first steam generator.

In various implementations, the steam generator is a heat recovery steamgenerator. The measurement of steam quality output by the steamgenerator may be performed in various implementations, which may thusinclude a measurement unit configured to determine a measured outputsteam quality and a controller configured to adjust a current outputsteam quality to within a specified range using the measured outputsteam quality as feedback. In such implementations, the controller isconfigured to cause fluid movement device to adjust a rate of fluid flowthrough the storage medium in accordance with the feedback and thespecified range of steam quality.

D. Carbon Removal

1. Problems to be Solved

Carbon dioxide is the largest contributor to global greenhouse gasemissions, with fossil fuel use being the primary source of carbon.About 20% of emissions come from industrial processes, which primarilyinvolve fossil fuel combustion for energy. In the U.S. alone, greenhousegas emissions totaled 6,577 million metric carbon tons of carbon dioxideequivalents. At least 16 states and Puerto Rico have enacted legislationestablishing reduction requirements for greenhouse gas (GHG) emissions.California, for example, has implemented GHG emissions reduction targetsthrough SB32, which requires that the state Air Resource Board (CARB)ensure GHG emissions reductions to 40% below 1990 levels by 2030.

These forces, combined with falling renewable energy prices, have drivena boom in renewables adoption, thus increasing the challenge ofbalancing energy supply and demand with added intermittent energysupply. Renewable energy curtailment has steadily increased, andoversupply conditions are expected to occur more often going forward. Atthe same time, in order to respond quickly to sudden losses ofgeneration and/or unexpected changes in load, there may be greater needfor expensive spinning and other operating reserves.

In addition, the energy produced through renewable means, for example,solar and wind, typically does not match the demand. Accordingly, thevalue of efficient solutions for energy storage has become increasinglyclear in order to continue increasing renewable fraction in our energysupply. Energy storage is able to provide backup power or heat whentraditional sources of energy (e.g., grid electricity) are lost orinterrupted. Energy stored as high temperature heat has multipleadvantages, including higher energy density, lower cost, increasedflexibility for use in industrial high temperature applications as wellas for producing power. Decarbonization may be particularly difficultfor industrial processes requiring very high temperatures, such as above1000° C.

Existing industrial heat processes are generally fired by fossil fuels,sometimes with enriched oxygen atmosphere for applications requiringvery high temperatures, for example greater than 1500° C. Such processescannot be switched to an intermittent renewal source because of the needfor continuous, high temperature heat. Meanwhile, some governmentsaround the world limit greenhouse gas emissions. For example, in Europe,the EU emissions trading system (EU ETS) uses a cap-and-trade method tolimit carbon emissions. Carbon dioxide prices are expected tosignificantly increase in the future.

At the end of 2019, the average price of carbon dioxide in Europe was€25/ton. Germany has announced prices in the range of €55-65 per tonafter 2026 and by 2050, carbon dioxide prices in the range of €100-€150per ton is expected. In the European cement industry alone, whichemitted 117 megatons of CO₂ in 2018, the current cost of the emission isapproximately €3 billion. Globally, energy-related CO₂ emissions werearound 33 gigatons in 2019.

Therefore, there is significant unmet need for technologies that cansignificantly reduce carbon emissions in industry, such as usingrenewable electricity. However, for very high temperature operationssuch as cement, glass, power and steel production, there are no reliableways to achieve the high temperatures needed by using only intermittentenergy sources.

Processes for separating carbon dioxide gas from exhaust gases that aregenerated by combustion of fuels may require a continuous flow of heatand electricity. Exhaust gases may increase during time periods of highdemand, when generated electricity costs are highest, and therefore, notdesirable for use in a carbon capture process. Alternatively, use ofrenewable sources of electricity are intermittent, and therefore notreliable for generating the required continuous flow of heat andelectricity. It is noted that use of “continuous source of heat andelectricity” is not intended to imply zero variation in temperatureand/or electrical power. Rather the term “continuous,” as used herein,indicates that the source of heat and/or electricity are capable ofproviding a sufficient amount of electricity and heat to maintain properoperation of a carbon dioxide separation process.

Calcium Looping is one example of a CO₂ capture technology that is basedon cyclic calcination/carbonation reaction of, for example, CaO. CaOreacts with CO₂ to generate CaCO₃. The forward reaction is calledcarbonation, and is exothermic, where CO₂ is captured onto the sorbent.The reverse reaction, calcination, is endothermic and releases a purestream of CO₂ which can be captured, compressed and stored. Such a cyclemay include an intermediate step of hydration to increase the cycle lifeof the sorbent. The calcination reaction (releasing of CO₂) requireshigh temperatures above 900° C. whereas the carbonation reaction(adsorption of CO₂) requires temperatures around 600-700° C.Intermediate hydration reactions may occur at temperatures 100-200° C.

While calcium looping with CO₂ and sometimes other gases such as SO2 isan important technology to decrease the carbon footprint, the largeenergy requirement, often met by burning fossil fuels in a pure streamof oxygen, poses additional challenges toward reducing the carbonintensity of the process.

There is an unmet need for a high temperature thermal energy storagesystem powered by renewable electricity that can provide the energyrequired to run such a process, making the calcium looping processcarbon negative.

2. Carbon Capture

While calcium looping offers promising methods for capturing and storingCO₂, the requirement in existing technologies for high temperature heatprovided by a fuel stream combined with pure oxygen reduces the overallcarbon capture efficiency. Such technologies may further require an airseparator which adds cost and complexity to the system.

The problem of generating constant power and heat from an intermittentpower source for use in a calcium-looping carbon dioxide separationprocess may be resolved by charging thermal storage units when theintermittent power source is available and generating the heat and powerfrom the thermal storage units. Use of such thermal storage units mayallow for continuous generation of heat and electricity from aninconsistent power source. Referring to FIG. 94 , a high temperaturethermal energy storage system powered by renewable electricity disclosedherein which uses some of the CO₂ generated as the thermal exchangefluid running through an example implementation system 100 eliminatesthe need for additional fuel or a pure oxygen stream. High temperatureheat can be used for the regeneration cycle, mid-range temperature heatfor the carbonation cycle, and low temperature heat can be used for thehydration reaction or to pre-heat the CO₂ stream entering the storagesystem. A truly carbon-negative calcium looping process can be coupledto any CO₂ producing processes and may have particular benefit in thecement production industry which can use spent calcium oxide to augmentfeedstock into the cement production process.

One application of the heated brick storage system is to drive acryogenic carbon removal process. In one case, the unit is used to powera continuous electric power generation source which in turn drives acarbon dioxide separation process, which uses cryogenic effects,compressing and cooling CO₂ to reduce its temperature until it becomes asolid, or in some embodiments a liquid. A supply of the electricalenergy needed to drive that process is derived from energy supplied by aturbine generator whose input heat can be provided by a thermal energystorage unit.

Many carbon capture processes, such as calcium looping, rather thanpurely using electric power (like the cryogenic process described above)also use thermal energy. The thermal energy may be used to regenerate asolid or liquid medium which captures carbon dioxide, then releases it(by being regenerated), and then is used again for one or more cycles tocapture further carbon dioxide. Thermal energy from a heat storage unitdescribed above can provide renewable based energy for this process.

High temperature heat may drive one implementation of a calcinationprocess, in a multi-step chemical reaction which involves the repeatedconversion of a calcium oxide to calcium carbonate using captured carbondioxide, and then calcination to release the carbon dioxide. Suchreactions take place at high temperatures, and high temperature heatfrom a heat storage unit described above can power this process,followed by the use of the remaining lower temperature heat to drive anelectrical generator, via a turbine heat-to-work process, includingsteam, CO₂ or Rankine cycle processes.

Such heat may be supplied as lower grade heat from the outlet of aturbine generator, into which high grade heat is supplied by a thermalstorage unit, such that some portion of energy is used in the form ofelectricity to drive pumps, and another portion of energy, in the formof heat, is used to drive regeneration. Both forms of energy may besupplied in an efficient manner using high temperature thermal energystorage.

Referring to FIG. 94 , in some example implementations, the integratedcogeneration system 400 can be configured to provide thermal andelectrical energy necessary to drive a carbon capture and sequestrationprocess. The processes of CO₂ separation from exhaust gases and CO₂capture directly from ambient air (Direct Air Capture, or DAC) commonlyuse processes where a capture media, which may be an absorbent liquid,an adsorbent solid, or a chemically reactive solid is exposed to fluegas or other CO₂-containing gas streams at a first temperature, thenheated to a second temperature which causes the selective release of theCO₂ into another fluid conduit, followed by a cooling of the capturemedia and its re-use in another cycle of capture and release.

Stored thermal energy derived from VRE may provide a continuous supplyof the necessary heat to drive this process. High-temperature air, orother type of fluid, may be directed to calcine or otherwise regeneratea high-temperature capture media. In one, steam may be directly suppliedby an HRSG to drive a capture process element such as an amine solventreboiler or adsorbent regenerator. In addition, or in place of steamfrom an HRSG, lower-pressure extracted steam from a steam turbine powercycle may be directed to provide heat to a solvent reboiler.

Electrical power generated by a steam turbine, organic Rankine cycleturbine, or supercritical CO₂ turbine may provide electric power todrive the CO₂ capture and compression equipment. Thus stored VRE mayprovide all energy necessary to drive a zero-emission carbon capturesystem 702 to enable separation of CO₂ from exhaust gases or ambientair.

One example of using thermal storage units in a carbon capture processincludes a carbon dioxide capture system that is configured to separatecarbon dioxide from exhaust gases using, for example, a calcium loopingprocess as described above.

FIG. 100 illustrates a direct air capture approach 11000 according tothe example implementations. A thermal storage system is included thatis configured to convert input electricity from an input energy supplyto stored thermal energy, the input energy supply having intermittentavailability, e.g., from VRE 11001, such as a renewable energy source.The example further includes a power generation system, includingthermal energy storage 11003 that provides hot fluid to an HRSG 11007,that is configured to convert the stored thermal energy to outputelectricity. This output electricity is provided to the carbon dioxidecapture system. The carbon dioxide capture system is configured tooperate using the provided electricity. In some embodiments, the thermalstorage system includes a thermal energy storage 11007 that isconfigured to heat a storage medium using the input electricity from theinput energy supply (VRE11001), as well as a blower that is configuredto circulate fluid through the heated storage medium, as explainedabove. The power generation system, in some embodiments, may include aheat exchanger that is configured to generate steam using circulatedfluid, and a steam turbine that is configured to generate the suppliedelectricity from the produced steam.

The carbon dioxide capture system may include thermal energy storage11005, which is configured to use a portion of stored thermal energy asheat to separate the carbon dioxide from the exhaust gases. For example,the heat may be used as part of a calcination cycle at calciner 11009used to release carbon dioxide from an adsorbent material that has beenused to capture the carbon dioxide. The thermal energy storage system,in some implementations, is configured to generate the outputelectricity in a substantially continuous manner, thus allowing thecarbon dioxide capture system to be operational as needed.

An example method for operating a thermal energy storage system ispresented in FIG. 95 . Method 5100 includes, at block 5110, converting,by a thermal energy storage system, input electricity from anintermittently availability energy supply to stored thermal energy. Forexample, a renewable energy source, such as solar or wind, may be usedto generate electricity which, in turn, is used to power heatingelements that supply heat to a storage medium. At block 5120, method5100 includes providing stored thermal energy from the thermal energystorage system to a steam turbine to generate electricity. The heatedstorage medium may be used to supply heat to a boiler that drives anelectricity generator (e.g., a steam-powered generator). Heat may betransferred, via a suitable fluid, from the storage medium to a heatexchanger that heats the boiler. Method 5100 further includes, at block5130, providing the generated electricity and heat from the thermalenergy storage system to a carbon dioxide capture system that separatescarbon dioxide from exhaust gases, wherein the output electricity andheat is provided at least at times when the energy supply is notavailable. Any suitable type of carbon dioxide capture process, such asa calcium looping process or cryogenic process, may be used. Use of athermal storage system may allow the stored heat to be used at timeswhen the energy source is not available, in addition to times when theenergy supply is available.

An example method for operating a carbon dioxide capture system is shownin FIG. 96 . Method 5200 includes, at block 5210, receiving, by a carbondioxide capture system, exhaust gases from combustion of a fuel source.The carbon dioxide capture system may include an absorber tower throughwhich, exhaust gases flow, the exhaust gases coming from a furnace thatis used to burn fossil fuels. At block 5220, method 5200 furtherincludes receiving, by the carbon dioxide capture system, electricitygenerated from a thermal energy storage system. In the present example,power for the carbon dioxide capture system is provided by anintermittent source, such as renewable energy sources. The thermalenergy storage system stores thermal energy using the intermittentlyavailability energy supply. Method 5200 further includes, at 5230,separating, by the carbon dioxide capture system, carbon dioxide fromexhaust gases using the received electricity and heat. Any suitable typeof carbon dioxide capturing process may be used, including the processesdisclosed herein. In some implementations, the carbon dioxide capturesystem may use both electricity and heat from the thermal energy storagesystem. The separating is performed at least at times in which theenergy supply is not available. Since an intermittent energy source isused to supply the thermal energy storage system, this thermal energystorage system is capable of providing continuous heat to be used by thecarbon dioxide capture system as a heat source and/or to generateelectricity.

3. Advantages of Disclosed Implementations

The example implementations related to carbon capture may have variousadvantages and benefits relative to traditional techniques. For example,the approaches described herein may address oversupply issues, as wellas promote additional carbon capture for very high temperatureindustrial applications.

For example, use of thermal storage units may allow use of electricitygenerated by the combustion of fuels. During time periods of lowelectricity demand, power generated from combustible fuels is used tocharge thermal storage units. During time periods of high electricitydemand, charging of the thermal units is ceased and the carbon captureprocess is powered by the charged thermal storage units. Accordingly,the thermal units may be charged when electricity costs are low and theproduced electricity, therefore, has less value. During the time periodsof high electricity demand, the produced has greater value and can besold to an electrical grid rather than being routed to the carboncapture process.

E. Additional Industrial Applications

1. Renewable Desalination

Desalination processes traditionally run continuously and a significantamount of the world's desalination currently comes from membranesystems. The vast majority of the desalination in some regions (e.g.,the Middle East), however, uses older thermal desalination technologythat is coupled to a combined cycle power station. The combined cyclepower station may have a combustion turbine and a steam turbine whichoutputs, for example, 70° C. condensation, which powers either amulti-stage flash or a multi-effect distillation production system. Thismay reduce the steam turbine electricity output by a few percent but maysignificantly reduce the electricity used to make water by desalination.In one example one ton of input steam makes four tons to seven tons ofoutput water.

In some use cases, the power station remains running to keepdesalination operational even when there is no other demand for theelectricity generated by the power station, which results in power beingwasted. With more renewable energy coming online, this may be anincreasingly pressing problem.

By incorporating a heat storage system in accordance with exampleimplementations, these problems may be addressed. The heat storagesystem may have an outlet temperature hotter than the outlet temperatureof the combustion turbine. Thus, the heat storage system may beconnected to a heat recovery steam generator with a separate air inletport, or a steam generator of the heat storage system may be run to makewater, firing no natural gas. The heat storage system may be charged byPV or run from grid power to absorb what would otherwise be overgeneration in the daytime and transition to true zero carbon water.

Thus, this system may be used to buffer peak electricity and providelevel load power. If the combustion turbine is not been de-installed,during periods of high electricity demand, such as during a hot summerday, the combustion turbine remains available and thermal storage can beadditionally deployed to run the steam turbine above nominal if desired.

One challenge in certain geographical regions (e.g., in the Middle East)is that a combustion turbine may produce around 18% less electricity ona hot day than it would on a cold day due to the lower combustion airdensity on the hot day. The disclosed heat storage system may be used tobring this steam mass flow and/or temperature back up when power fromthe turbine is drooping. All that can be electric so base load water canbe made, but also includes its built-in topping power for peakelectricity demand.

The heated brick energy storage systems described herein may be capableof producing higher output temperatures which may allow directintegration into existing desalination systems or may serve as the basisfor a dedicated desalination system.

One beneficial element of these heated brick heat storage systems isthat they may be retrofitted into existing plants to capture what wouldotherwise be overgeneration in the system. It should be noted that thedisclosed heat storage system, coupled with a combined cycle powerstation can also drive a reverse osmosis system or other industrialprocesses, which may require round the clock power, with renewableenergy.

2. Glass Production

Glass production typically requires temperatures ranging from 1500-1700°C. in a melting furnace where raw materials transform through a sequenceof chemical reactions to form molten glass. The melting processrepresents over half of energy use in glass production. The metal bathmay require temperatures from 1100° C. to around 600° C. at the outletbefore the molten glass is annealed at 600° C. In some traditionalimplementations, the thermal energy required for glass production isprovided by fossil fuel combustion and in some cases, electricalheating. Glass production is thus a highly energy-intensive process andglobal demand continues to increase for glass. According to theInternational Energy Agency, the container and flat glass industries(which combined account for 80% of glass production) emit over 60megatons of CO₂ per year (IEA 2007) and energy use accounts for about15% of total glass production costs.

Glass melting furnaces are complemented by a set of heat recoveryregenerators which recover heat from the end of a melt furnace and useit to pre-heat the combustion air, e.g., to 900-1200° C. prior to thetemperature being raised further through the burner to about 1700° C.,e.g., 1700° C.

The high temperature energy storage system disclosed herein may have thecapability to provide all thermal needs of the glass production system,including the high temperature melt furnace. In one exampleimplementation, glass regenerators can be replaced by high temperaturethermal energy storage systems disclosed herein to provide hightemperature air or another gas and eliminate the need for a burner.

Because glass production is a round-the-clock process, an energy storagesystem may be used in one implementation to replace a significant amountof the input energy with intermittent renewable energy. The reduction orelimination of combustion gases may also reduce the amount ofundesirable combustion products in the glass furnace. Nitrogen oranother gas can be used in a closed loop through the high temperaturethermal energy storage system, and into the float tank, reducing cost ofair separation and reducing the production of undesirable side productof nitrogen oxides (NOx) produced by thermal reaction of nitrogen andoxygen in air.

In an alternative example implementation, the heated air from existingregenerators can be fed into the high temperature thermal energy storagesystem disclosed herein which then produces output fluid at atemperature utilized by the melt furnace. This may also reduce oreliminate need for a burner and additional combustion of fossil fuels.

3. Iron and Steel Production

Traditionally, crude steel is made using blast furnaces. Steelmaking mayrequire high temperatures, such as approximately 1600° C., e.g., 1600°C. Every ton of steel produced in 2018 emitted on average 1.85 tons ofcarbon dioxide including agglomeration, iron- and steelmaking, castingand hot rolling, and accounts for approximately 30% of the globalindustrial CO₂ emissions. Therefore, there is a substantial unmet needfor reduction of the carbon intensity of steelmaking. The European steelindustry aims to reduce CO₂ emission by 80-95% by 2050 to meet therequirements of the Paris Agreement. Such drastic reduction may bedifficult or impossible to achieve using traditional equipment.

Direct reduction processes used with an electric arc furnace may providea pathway for substantial CO₂ emission reduction in the steel industry.Use of natural gas as the reducing agent reduces CO₂ emissions byapproximately ⅓ compared to the traditional blast furnace route. Usingrenewable H₂ as a reducing agent further reduces emissions. However, theprocess may be thermally unfavorable due to the endothermic nature ofthe reaction between hydrogen and iron oxide.

For example, 800 m{circumflex over ( )}3 (STP)/t DRI (cubic meters atstandard temperature and pressure per metric ton of direct reduced iron)of hydrogen may be necessary for operation with hydrogen alone. Thereduction process itself needs 550 m{circumflex over ( )}3 (STP)/t DRI,whereas 250 m{circumflex over ( )}3 STP/t DRI of hydrogen is required asfuel for the gas heater. An additional ˜50 m{circumflex over ( )}3(STP)/t DRI of natural gas may be needed in order to maintain thetemperature and carbon content of the DRI. The temperature reductionfrom the hydrogen reaction can be compensated by the addition of naturalgas. The exothermic reaction is between iron oxide and CO. Incomparison, natural gas process requires approximately 259 m{circumflexover ( )}3 STP/t DRI.

The ultrahigh temperatures produced by the thermal energy storage systemof the example implementations may reduce carbon emissions from thesteelmaking process. The ability to obtain some of the highesttemperatures of the steelmaking operation near 1600-2000° C. means thatthermal process heat needs in the blast furnace can be met using arenewable-energy-charged thermal storage system around the clock asdescribed above. In addition, the gas composition heated inside thethermal storage unit may be tuned/selected to further increaseproduction efficiency, to retrofit fossil fuel systems to a directreduction process without the need for significant equipmentmodification, or both. In other words, a traditional system may berelatively simply retrofitted to be electrified using intermittentelectricity sources such as a PV system. For example, hydrogen ornatural gas can directly be used as the heat exchange fluid which isheated by the thermal storage system and also to directly reduce the oreinto steel.

To the extent a term used in a claim is not defined below, it should begiven the broadest definition persons in the pertinent art have giventhat term as reflected in printed publications and issued patents at thetime of filing. For example, the following terminology may be usedinterchangeably, as would be understood to those skilled in the art:

A Amperes

AC Alternating current

DC Direct current

DFB Dual Fluidized Bed

EAR Enhanced Oil Recovery

EV Electric vehicle

GT Gas turbine

HRSG Heat recovery steam generator

kV kilovolt

kW kilowatt

MED Multi-effect desalination

MPPT Maximum power point tracking

MSF Multi-stage flash

MW megawatt

OTSG Once-through steam generator

PEM Proton-exchange membrane

PV Photovoltaic

RSOC Reversible solid oxide cell

SOEC Solid oxide electrolyzer cell

SOFC Solid oxide fuel cell

ST Steam turbine

TES Thermal Energy Storage

TSU Thermal Storage Unit

Additionally, the term “heater” is used to refer to a conductive elementthat generates heat. For example, the term “heater” as used in thepresent example implementations may include, but is not limited to, awire, a ribbon, a tape, or other structure that can conduct electricityin a manner that generates heat. The composition of the heater may bemetallic (coated or uncoated), ceramic or other composition that cangenerate heat.

While foregoing example implementations may refer to “air”, includingCO₂, the inventive concept is not limited to this composition, and otherfluid streams may be substituted therefor for additional industrialapplications. For example but by way of limitation, enhanced oilrecovery, sterilization related to healthcare or food and beverages,drying, chemical production, desalination and hydrothermal processing(e.g. Bayer process.) The Bayer process includes a calcination step. Thecomposition of fluid streams may be selected to improve product yieldsor efficiency, or to control the exhaust stream.

In any of the thermal storage units, the working fluid composition maybe changed at times for a number of purposes, including maintenance orre-conditioning of materials. Multiple units may be used in synergy toimprove charging or discharging characteristics, sizing or ease ofinstallation, integration or maintenance. As would be understood bythose skilled in the art, the thermal storage units disclosed herein maybe substituted with other thermal storage units having the necessaryproperties and functions; results may vary, depending on the manner andscale of combination of the thermal storage units.

As used in the description herein and throughout the claims that follow,the meaning of “a,” “an,” and “the” includes plural reference unless thecontext clearly dictates otherwise. Also, as used in the descriptionherein, the meaning of “in” includes “in” and “on” unless the contextclearly dictates otherwise.

The recitation of ranges of values herein is merely intended to serve asa shorthand method of referring individually to each separate valuefalling within the range. Unless otherwise indicated herein, eachindividual value is incorporated into the specification as if it wereindividually recited herein.

All methods described herein can be performed in any suitable orderunless otherwise indicated herein or otherwise clearly contradicted bycontext. The use of any and all examples, or exemplary language (e.g.,“such as”) provided with respect to certain example implementationsherein is intended merely to better illuminate the exampleimplementation and does not pose a limitation on the scope of theexample implementation otherwise claimed. No language in thespecification should be construed as indicating any non-claimed elementessential to the practice of the example implementation.

Groupings of alternative elements or example implementations of theexample implementation disclosed herein are not to be construed aslimitations. Each group member can be referred to and claimedindividually or in any combination with other members of the group orother elements found herein. One or more members of a group can beincluded in, or deleted from, a group for reasons of convenience and/orpatentability. When any such inclusion or deletion occurs, thespecification is herein deemed to contain the group as modified thusfulfilling the written description of all groups used in the appendedclaims.

In the specification, reference may be made to the spatial relationshipsbetween various components and to the spatial orientation of variousaspects of components as the devices are depicted in the attacheddrawings. However, as will be recognized by those skilled in the artafter a complete reading of the present application, the devices,members, devices, etc. described herein may be positioned in any desiredorientation. Thus, the use of terms such as “above,” “below,” “upper,”“lower,” “first”, “second” or other like terms to describe a spatialrelationship between various components or to describe the spatialorientation of aspects of such components should be understood todescribe a relative relationship between the components or a spatialorientation of aspects of such components, respectively, as the devicedescribed herein may be oriented in any desired direction.

In interpreting the specification, all terms should be interpreted inthe broadest possible manner consistent with the context. In particular,the terms “comprises” and “comprising” should be interpreted asreferring to elements, components, or steps in a non-exclusive manner,indicating that the referenced elements, components, or steps may bepresent, or utilized, or combined with other elements, components, orsteps that are not expressly referenced. Where the specification claimsrefer to at least one of something selected from the group consisting ofA, B, C . . . and N, the text should be interpreted as requiring onlyone element from the group, not A plus N, or B plus N, etc.

While the foregoing describes various example implementations of theexample implementation, other and further example implementations of theexample implementation may be devised without departing from the basicscope thereof. The scope of the example implementation is determined bythe claims that follow. The example implementation is not limited to thedescribed example implementations, versions or examples, which areincluded to enable a person having ordinary skill in the art to make anduse the example implementation when combined with information andknowledge available to the person having ordinary skill in the art.

Subject Matter of Claims for Future Examination

Following are sets of claims relating to various embodiments accordingto the present disclosure. Claim set 1 matches the set of claims 1-56 asfiled herein for examination. Claim sets 2-7 include independent claimsmatching the independent claims as filed herein for examinationbeginning with claim 57. The dependent claims in claim sets 2-7, andclaims sets 8-9, are reserved for examination in future applications.

The claims below can be grouped as follows:

Claims 1-56 include, inter alia, claims relating to physical structuresof systems according to the present disclosure including bricks, stacks,heating apparatus, radiation chambers and related structures andprocesses, including once-through steam generators.

Claims 57-297 include, inter alia, claims relating to control processes,method and structures, including those relating to charging,discharging, deep discharging, and integrations of systems with variablerenewable electricity systems and industrial processes.

Claims 298-321 include, inter alia, claims relating to electronicdesigns and processes for systems according to the present disclosure,including DC-DC conversion systems and techniques.

Claims 322-352 include, inter alia, claims relating to application ofsystems and methods according to the present disclosure to calcining andother industrial processes.

Claims 353-594 include, inter alia, claims relating to application ofsystems and methods according to the present disclosure to solid-stateelectrolysis systems and processes.

Claims 595-629 include, inter alia, claims relating to application ofsystems and methods according to the present disclosure to cogenerationsystems.

Claims 630-635 include, inter alia, claims relating to application ofsystems and methods according to the present disclosure to selectiveapplication of discharge energy to different uses and processes basedupon demand and other criteria.

Claim 636 describes various specific components and characteristics of aTES system.

Claims 637-643 include, inter alia, claims relating to application ofsystems and methods according to the present disclosure to carboncapture processes.

Introductory comments are provided to some of the claims below tohighlight features and advantages of those claims.

Bricks with radiation chambers: Radiative heating via radiation cavitiesand convective discharging/heating via air movement, as well as internalconduction, more evenly distributes heat through the assemblage ofblocks.

1. A system for thermal energy storage and delivery, comprising: athermal storage assemblage (4100) including a plurality of thermalstorage blocks, wherein at least some of the thermal storage blocksinclude multiple radiation cavities and multiple fluid flow slots,wherein some of the radiation cavities and some of the fluid flow slotsare configured to define fluid pathways through the thermal storageblocks;

a plurality of heater elements (3607) positioned within the thermalstorage assemblage and adjacent to at least some of the radiationcavities, wherein each of the plurality of heater elements is configuredto heat at least one of the thermal storage blocks via energy radiatedinto multiple ones of the radiation cavities and onto surfaces thatbound the respective radiation cavities; and

a fluid movement system (213, 4223) configured to direct a stream offluid through the fluid pathways.

Radiation in a direction different from fluid movement.

2. The system of claim 1, wherein at least some of storage blocks arepositioned such that heater elements positioned adjacent to some of theradiation cavities emit heat primarily in a radiation direction that isdifferent than a fluid flow direction through corresponding fluidpathways.

3. The system of claim 2, wherein the radiation direction issubstantially orthogonal to the fluid flow direction.

Fluid pathways oriented in a vertical direction.

4. The system of claim 2, wherein the fluid flow direction through thefluid pathways is substantially vertical and at least some of the heaterelements are horizontally adjacent to some of the radiation cavities.

5. The system of claim 2, wherein the heater elements, the storageblocks and the radiation cavities are configured to provide asubstantially vertical thermocline wherein an upper portion of thethermal storage assemblage is at a higher temperature than a lowerportion of the thermal storage assemblage.

Each radiative cavity having multiple slots.

6. The system of claim 1, wherein at least one of the fluid pathwaysincludes multiple fluid flow slots that open to a particular radiationcavity and the stream of fluid passes through the multiple fluid flowslots from the particular radiation cavity.

Alternating cavities.

7. The system of claim 1, wherein a fluid pathway includes multiplecavities and multiple fluid flow slots, is oriented for substantiallyvertical fluid flow, and includes alternating radiation cavities andsets of one or more fluid flow slots in the vertical direction.

Slots may receive radiation indirectly.

8. The system of claim 1, wherein the fluid flow slots are positionedsuch that radiative energy from the heater elements arrives at the fluidflow slots indirectly by reradiation via one or more radiation cavities.

Slots are elongated. The shape of the openings reduces the amount oflaminar flow, which may keep fluid within the openings at a more uniformtemperature.

9. The system of claim 1, wherein the fluid flow slots are elongate witha longer dimension and a shorter dimension.

Slot orientation, e.g., for zigzag blocks. The direction of the openingsmay avoid blocking conductive transfer through the bricks resulting fromabsorbing radiation in the cavities.

10. The system of claim 8, wherein fluid flow slots of at least onethermal storage block are oriented with their longer dimension inmultiple different directions.

Upper blocks taller. The upper part of the stack is hotter, so largerbricks may handle the heat better. Smaller bricks at the bottom may alsoprovide more structural stability.

11. The system of claim 1, wherein thermal storage blocks are positionedin multiple tiers, wherein the height of radiation cavities and fluidflow slots in a first tier is less than the height of radiation cavitiesand fluid flow slots in a second tier that is higher than the firsttier.

Control heater elements based on vertical height Optimal heater elementenergy may vary based on temperature, and the stop of the stack istypically hotter than the bottom. This may increase thermal retentionefficiency.

12. The system of claim 1, further comprising:

control circuitry configured to provide energy to the heater elements;

wherein thermal storage blocks are positioned in multiple tiers; and

wherein the control circuitry is configured to provide different amountsof energy to the heater elements in at least some of the multiple tiers.

Independent vent control for insulated sets of stacks. This mayfacilitate separate charge/discharge of cells in a TSU.

13. The system of claim 1,

wherein the thermal storage assemblage includes:

multiple stacks of thermal storage blocks, including a first set ofstacks (4107) that is thermally isolated from a second set of stacks(4109); and

vents (4111, 4113) located under the first set of stacks and the secondset of stacks and configured to be independently controlled to directflow of the stream of fluid into the first set of stacks and the secondset of stacks.

Cavities are larger than slots. Larger radiation cavities that would beneeded for airflow may facilitate uniform radiative heating.

14. The system of claim 1, wherein the volumes of at least someradiation cavities are greater than neighboring sets of one or morefluid flow slots of a given fluid pathway.

Larger blocks may reduce costs of block construction and reduce frictiondamage between blocks in a stack. Certain shapes may also providestructural safety, e.g., in case of seismic events.

15. The system of claim 1, wherein at least one of the thermal storageblocks bounds multiple radiation cavities and multiple openings that areat least partially defined by one or more other thermal storage blocks.

Tall blocks.

16. The system of claim 1, wherein a thermal storage block includesradiation cavities and fluid flow slots at multiple vertical elevations.

Small slots above heating elements may improve overall fluid flow andeven heat distribution.

17. The system of claim 1, wherein at least some of the thermal storageblocks include fluid flow slots in a block portion positioned above atleast one of the heater elements.

Failsafe vent.

18. The system of claim 1, wherein the thermal storage assemblageincludes:

an enclosure;

wherein the enclosure includes a first vent with a first vent closure,the first vent forming a passage between an interior of the enclosureand an exterior, wherein the apparatus is configured to maintain thefirst vent closure in a closed position during an operating condition ofthe fluid movement system; and

a failsafe mechanism configured to open the first vent closure inresponse to a nonoperating condition of the fluid movement system.

Dynamic insulation may allow use of less expensive insulation, improveequipment life, or both.

19. The system of claim 1, wherein the thermal storage assemblageincludes:

a first enclosure having an interior surface;

a second enclosure having an exterior surface, the second enclosurepositioned within the first enclosure, wherein the thermal storageblocks are positioned in the second enclosure; and

a fluid passage bounded by the exterior surface and the interior surfaceand in communication with the fluid pathways, wherein the fluid movementsystem is configured to direct the stream of fluid through the fluidpassage and then through the fluid pathways.

Interlocking shelf portions may improve structural stability and reducefriction damage.

20. The system of claim 1, wherein the thermal storage blocks includeshelf portions (3305) that interlock when the thermal storage blocks arepositioned in a stack.

Cavity and slot heights are substantially the same.

21. The system of claim 1, wherein the radiation cavities and fluid flowslots at a given vertical elevation have substantially the same height.

22. The system of claim 1, further comprising:

-   -   an outlet (4303) configured to output gas heated by the thermal        storage assemblage.

23. The system of claim 1, wherein the heater elements are connectableto receive energy from one or more energy sources of the following listof energy sources: solar, wind, hydroelectric and geothermal.

24. The system of claim 1, wherein the heater elements are alsoconfigured to heat the thermal storage blocks via conduction.

25. The system of claim 1, wherein the fluid includes one or more gases.

26. The system of claim 1, wherein the fluid is air.

27. The system of claim 1, wherein the fluid movement system includes ablower configured to direct the stream of fluid.

Failsafe Venting

28. A thermal storage unit (4100), including:

a first enclosure;

a thermal storage assemblage comprising a plurality of thermal storageblocks within the first enclosure;

a plurality of heater elements positioned within the assemblage andconfigured to heat the plurality of thermal storage blocks;

a fluid movement system configured to direct a stream of fluid throughfluid pathways in the plurality of thermal storage blocks;

wherein the first enclosure defines an interior and an exterior andincludes a first vent with a first vent closure, the first vent forminga first passage between the interior and the exterior; and

a failsafe mechanism configured to maintain the first vent closure in aclosed position during an operating condition of the fluid movementsystem and to open the first vent closure in response to a nonoperatingcondition of the fluid movement system.

Second vent is open to air input, allowing passive cooling using thechimney effect, which draws cooler fluid into the bottom of the stacksand prevents overheating.

29. The thermal storage unit of claim 28, wherein the first enclosureincludes a second vent having a second vent closure and forming a secondpassage between the interior and the exterior, the second passage beingconfigured to allow passage of the fluid to the first passage; and

wherein the failsafe mechanism is configured to open the second ventclosure in response to the nonoperating condition of the fluid movementsystem to allow passage of external fluid through the second vent intothe interior via the second passage, through the first passage and outof the first enclosure through the first vent.

30. The thermal storage unit of claim 29, wherein the first passage isconfigured to permit flow of internal heated fluid out of the firstenclosure by buoyancy of the internal heated fluid and to permit entryof the external fluid into the first passage as the internal heatedfluid flows out of the first enclosure.

Rotating door.

31. The thermal storage unit of claim 29, wherein the first vent closureand the second vent closure are different portions of a vent door,wherein the thermal storage unit is configured to rotate the vent doorto close the first and second vents during the operating condition ofthe fluid movement system.

Block input to steam generator.

32. The thermal storage unit of claim 30, further comprising:

a steam generator including an input comprising a duct and configured toreceive fluid heated by the thermal storage blocks via the duct;

wherein the failsafe mechanism is configured to close the duct inresponse to the nonoperating condition of the fluid movement system.

Vent door used to block the steam generator input.

33. The thermal storage unit of claim 32, wherein the first vent closureis positioned to close the duct when the first vent closure is open forthe first vent.

Open exterior input to steam generator.

34. The thermal storage unit of claim 32, wherein the second vent formsa passage from the exterior into the input of the steam generator.

Failsafe passively draws fluid through dynamic insulation passage.

35. The thermal storage unit of claim 33, further comprising:

a second enclosure having an interior surface, wherein the firstenclosure is positioned within the second enclosure;

a fluid passage bounded by an exterior surface of the first enclosureand the interior surface and in communication with the fluid pathways;

wherein the fluid movement system, during the operating condition, isconfigured to direct the stream of fluid through the fluid passagebefore directing the stream of fluid through the fluid pathways;

wherein the first vent closure defines a portion of the fluid passage inthe closed position; and

wherein the open position of the first and second vent closures in thenonoperating condition of the fluid movement system is configured toallow passage of external fluid through the second vent into theinterior via the second passage, through the first passage and out ofthe first enclosure through the first vent.

Passive fluid movement through inactive blower.

36. The thermal storage unit of claim 35, wherein the open position ofthe first and second vent closures in the nonoperating condition of thefluid movement system draws fluid from the exterior through the fluidpassage via a nonoperating blower of the fluid movement system.

Door for outside enclosure.

37. The thermal storage unit of claim 35, further comprising a thirdvent having a third vent closure, wherein the third vent is included inthe second enclosure and forms a passage between the interior of thesecond enclosure and its exterior, wherein the failsafe mechanism isconfigured to open the third vent closure in response to thenonoperating condition of the fluid movement system.

Steam generator being positioned inside enclosure helps keep leaksinternal, reducing the impact of leaks in the steam generator.

38. The thermal storage unit of claim 35, wherein at least a portion ofthe steam generator that receives heated fluid via the duct is includedin the second enclosure.

39. The thermal storage unit of claim 28, wherein the failsafe mechanismis configured to hold the first vent cover in a closed position usingelectrical power during the operating condition.

Clutch/gravity implementation of failsafe door opening mechanism.

40. The thermal storage unit of claim 39, wherein the failsafe mechanismincludes a worm drive gear configured to close the first vent cover andan electrical clutch configured to hold the first vent cover in theclosed position, wherein the first vent cover is configured to open dueto gravitational force when the electrical clutch is not powered.

Alternative implementation of failsafe mechanism.

41. The thermal storage unit of claim 39, wherein the failsafe mechanismincludes an electrical switch and a motor.

Dynamic Insulation—Apparatus

42. A thermal storage unit (4100), including:

a first enclosure having an interior surface;

a thermal storage assemblage comprising a plurality of thermal storageblocks positioned in a second enclosure having an exterior surface, thesecond enclosure positioned within the first enclosure, wherein thethermal storage blocks include fluid pathways;

a plurality of heater elements positioned within the assemblage andconfigured to heat the thermal storage blocks; and

a fluid passage bounded by the exterior surface and the interior surfaceand in communication with the fluid pathways; and

a fluid movement system configured to direct a stream of fluid throughthe fluid passage and the fluid pathways.

Details on where the passage directs fluid.

43. The thermal storage unit of claim 42, wherein the fluid movementsystem is configured to direct the stream of fluid upward along a wallof the second enclosure, across a roof of the second enclosure, downalong one or more other walls of the second enclosure, then into bottomopenings of the fluid pathways of the thermal storage blocks.

Bottom louvers control flow into stacks.

44. The thermal storage unit of claim 42, further comprising:

louvers configured to independently control flow of fluid from the fluidpassage into different sets of fluid pathways.

Failsafe vents use dynamic insulation pathway for failsafe venting,improving safety of the system without requiring separate ventingpassages or powered mechanisms.

45. The thermal storage unit of claim 42,

wherein the second enclosure includes:

a first vent with a first vent closure, the first vent forming a firstpassage between an interior of the first enclosure and an exterior,wherein the thermal storage unit is configured to maintain the firstvent closure in a closed position during an operating condition of thefluid movement system; and a second vent having a second vent closureand forming a second passage between the interior and the exterior;

wherein the thermal storage unit includes a failsafe mechanismconfigured to open the first and second vent closures in response to anonoperating condition of the fluid movement system; and

wherein the open position of the first and second vent closures in thenonoperating condition of the fluid movement system are configured toallow passage of external fluid through the second vent into theinterior via the second passage, through the first passage, through thefluid pathways and out of the first enclosure through the first vent.

46. The thermal storage unit of claim 45, wherein the first and secondvent closures form a portion of the fluid passage when in the closedposition.

Pressure differential between dynamic insulation pathway and stacksreduces impact of internal leaks.

47. The thermal storage unit of claim 42, wherein the thermal storageunit is configured to operate in one or more states in which fluidpressure in the fluid passage is greater than fluid pressure within thesecond enclosure.

Source of fluid for dynamic insulation.

48. The thermal storage unit of claim 42, wherein the stream of fluidincludes recycled fluid from a steam generator that generates steamusing heated fluid from the thermal storage blocks.

Methods Including Radiation Cavities, Dynamic Insulation

49. A method, comprising:

heating a stack of thermal storage blocks in a thermal storage unit(TSU) that includes a plurality of thermal storage blocks, wherein atleast some of the thermal storage blocks include multiple radiationcavities and multiple fluid flow slots, wherein some of the radiationcavities and some of the fluid flow slots are configured to define fluidpathways through the thermal storage blocks;

wherein the heating is performed by a plurality of heater elements(3607) positioned within at least some of the thermal storage blocks andadjacent to some of the radiation cavities, via energy radiated intomultiple ones of the radiation cavities and onto surfaces that bound therespective radiation cavities within the at least one thermal storageblock; and

directing fluid through the TSU such that a stream of fluid passesthrough the TSU, including through the fluid pathways.

Radiative transfer in cavities improves heat distribution relative toimplementations without radiation cavities (e.g., which might receiveradiation along one wall of a thermal storage brick).

50. The method of claim 49, wherein at least three surfaces of aradiation cavity receive energy radiated from a heater element.

51. The method of claim 50, wherein the fluid flow slots receiveradiative energy from the heater element indirectly by reradiation viaone or more radiation cavities.

Induced turbulent flow in elongated slots.

52. The method of claim 49, wherein one or more of the plurality ofopenings are elongated and shaped to introduce turbulent flow of thefluid directed through the one or more of the plurality of openings.

53. An apparatus, comprising:

a thermal storage unit (TSU) (4100) including a plurality of thermalstorage means, wherein at least some of the thermal storage meansinclude multiple radiation cavities and multiple fluid flow slots,wherein some of the radiation cavities and some of the fluid flow slotsare configured to define fluid pathways through the thermal storagemeans;

heater means (3607) positioned within at least some of the thermalstorage means and adjacent to some of the radiation cavities, whereinthe heater is configured to heat at least one of the thermal storagemeans via energy radiated into multiple ones of the radiation cavitiesand onto surfaces that bound the respective radiation cavities withinthe at least one thermal storage means;

fluid movement means (213, 4223) for directing a stream of fluid throughthe TSU, including through the fluid pathways.

Radiation chamber.

54. An apparatus, comprising:

one or more thermal storage blocks that define a radiation chamber and afluid flow slot positioned above the radiation chamber to define a fluidpathway in a first direction;

a heater element positioned adjacent to the radiation chamber in asecond, different direction, wherein the radiation chamber is open on atleast one side to the heater element; and

a fluid movement system configured to direct a stream of fluid throughthe fluid pathway in the first direction.

Alternating “checkerboard” pattern of blocks and radiation cavities at agiven tier facilitates rapid and uniform heat distribution.

55. A system for thermal energy storage and delivery, including:

a plurality of thermal storage blocks positioned to define:

a first tier that includes an alternating pattern of block portions,with radiation cavities between neighboring block portions;

a second tier that includes an alternating pattern of block portions,with radiation cavities between neighboring block portions, whereinsecond-tier block portions are positioned adjacent first-tier radiationcavities, and second-tier radiation cavities are positioned adjacentfirst-tier block portions;

fluid flow slots formed in some of the block portions of the thermalstorage blocks, the fluid flow slots and radiation cavities positionedto form multiple fluid flow paths through the system;

a plurality of heating elements positioned adjacent multiple ones of theradiation cavities in the first and second tiers and configured to heatthe plurality of thermal storage blocks via energy radiated intomultiple ones of the cavities and onto surfaces that bound the radiationrespective cavities within the thermal storage blocks; and

a blower configured to direct a stream of fluid through the multiplefluid flow paths.

56. The system of claim 55, wherein the heater elements, the storageblocks and the radiation cavities are configured to provide asubstantially vertical thermocline wherein an upper portion of thethermal storage assemblage is at a higher temperature than a lowerportion of the thermal storage assemblage.

Lead-Lag Process and Deep Discharge to Prevent Thermal Runaway

Deep discharge.

57. A thermal energy storage system (10) configured to produce an outputfluid flow (20), the thermal energy storage system comprising:

-   -   a first assemblage (14A) of first thermal storage blocks (13A)        and a second assemblage (14B) of second thermal storage blocks        (13B), the first and second thermal storage blocks configured to        store thermal energy; and    -   a control system (15) configured to:        -   direct fluid flows during a first discharge period (2067d1)            such that the first assemblage, but not the second            assemblage, is discharged to within a deep-discharge            temperature region (2063r); and        -   direct fluid flows during a second discharge period (2067d2)            such that the second assemblage, but not the first            assemblage, is discharged to within the deep-discharge            temperature region.

58. The thermal energy storage system of claim 57, wherein the controlsystem is configured, during successive discharge periods (2067d1,2067d2), to alternate between:

-   -   directing fluid flows to discharge the first assemblage, but not        the second assemblage, to within the deep-discharge temperature        region; and    -   directing fluid flows to discharge the second assemblage, but        not the first assemblage, to within the deep-discharge        temperature region.

59. The thermal energy storage system of claim 57, wherein the controlsystem is configured to:

maintain the output fluid flow at a specified temperature profile(2065b); and

in successive discharge periods (2069bd1, 2067bd2), alternate between:

-   -   discharging the first assemblage to within the deep-discharge        temperature region while discharging the second assemblage to a        current value (2079b) of the specified temperature profile        (2065b); and    -   discharging the second assemblage to within the deep-discharge        temperature region while discharging the first assemblage to the        current value (2079ba) of the specified temperature profile        (2065b); and

60. The thermal energy storage system of claim 57, wherein the controlsystem is configured to:

maintain the output fluid flow at a specified temperature profile(2065); and

in successive discharge periods (2069cd1, 2069cd2), alternate between:

-   -   discharging the first assemblage to within the deep-discharge        temperature region while discharging the second assemblage to a        first buffer temperature (2085c) above the specified temperature        profile; and    -   discharging the second assemblage to within the deep-discharge        temperature region while discharging the first assemblage to a        second buffer temperature (2085ca) above the specified        temperature profile.

61. The thermal energy storage system of claim 60, wherein the controlsystem is configured to:

maintain the output fluid flow at a specified temperature profile; and

in successive discharge periods (2069d, 2069da), alternate between:

-   -   discharging the first assemblage to within the deep-discharge        temperature region while 1) discharging the second assemblage to        the first buffer temperature (2085d) and 2) maintaining fluid        flow to the first assemblage in a trickle mode (2089d); and    -   discharging the second assemblage to within the deep-discharge        temperature region while 1) discharging the first assemblage to        the second buffer temperature (2085da) and 2) maintaining fluid        flow to the second assemblage in the trickle mode (2089da).

62. The thermal energy storage system of claim 61, wherein, in thetrickle mode, fluid flow to a given assemblage being deeply dischargedis greater than 0% and less than 10% of a maximum possible flow to thegiven assemblage.

63. The thermal energy storage system of claim 57, wherein the controlsystem is configured to:

-   -   use a first set of flow parameters during a first discharge        period (2069ed1) to maintain the output fluid flow at a first        temperature (2090e) specified by a non-constant temperature        profile (2065e);    -   use a second, different set of flow parameters during the first        discharge period (2069ed1) to maintain the output fluid flow at        a second, different temperature (2091e) specified by the        non-constant temperature profile; and

maintain the output fluid flow at second, different temperature during afirst charging period (2069ec1) by keeping a first fluid flow for thefirst assemblage at a relatively constant proportion to a second fluidflow for the second assemblage.

64. The thermal energy storage system of claim 57, further comprising:

-   -   an inlet valve configured to admit a bypass fluid flow that        bypasses the first and second assemblages during discharge        periods, the bypass fluid flow having a bypass temperature that        is lower than a delivery temperature of the output fluid flow;        and    -   wherein the control system is configured to use the bypass fluid        flow to produce the output fluid flow during discharge periods.

65. The thermal energy storage system of claim 64, wherein discharging agiven one of the first or second assemblages to within thedeep-discharge temperature region includes cooling the given assemblageto a discharge temperature approximately equal to the bypasstemperature.

66. The thermal energy storage system of claim 64, wherein:

-   -   an upper end temperature of the deep-discharge temperature        region is substantially below a delivery temperature of the        output fluid flow; and    -   a lower end temperature of the deep-discharge temperature region        is below the upper end temperature and is equal to the bypass        temperature.

67. The thermal energy storage system of claim 64, wherein:

-   -   an upper end temperature of the deep-discharge temperature        region is closer to the bypass temperature than to the delivery        temperature; and    -   a lower end temperature of the deep-discharge temperature region        is below the upper end temperature and is equal to the bypass        temperature.

68. The thermal energy storage system of claim 64, wherein:

-   -   a midpoint temperature is midway between the bypass temperature        and the delivery temperature;    -   an upper end temperature of the deep-discharge temperature        region is closer to the bypass temperature than to the midpoint        temperature; and    -   a lower end temperature of the deep-discharge temperature region        is below the upper end temperature and is equal to the bypass        temperature.

69. The thermal energy storage system of claim 57, wherein the controlsystem is configured to monitor thermal discharge information for thefirst and second assemblages in order to determine bounds of thedeep-discharge temperature region.

70. The thermal energy storage system of claim 57, wherein the controlsystem is configured to determine bounds of the deep-dischargetemperature region based on a computer program that models behavior ofthe first and second assemblages.

71. The thermal energy storage system of claim 64, wherein the controlsystem is configured to produce the output fluid flow by causing:

-   -   mixing, during an initial portion of the first discharge period,        of a first fluid flow from the first assemblage with the bypass        fluid flow;    -   mixing, during a subsequent portion of the first discharge        period, of the first fluid flow with a second fluid flow from        the second assemblage;    -   mixing, during an initial portion of the second discharge        period, of the second fluid with the bypass fluid flow; and    -   mixing, during a subsequent portion of the second discharge        period, of the second fluid flow with first fluid flow.

72. The thermal energy storage system of claim 71, wherein the controlsystem is configured to:

initiate the subsequent portion of the first discharge period based on acurrent temperature of the first fluid flow falling below the deliverytemperature; and

initiate the subsequent portion of the second discharge period based ona current temperature of the second fluid flow falling below thedelivery temperature.

73. The thermal energy storage system of claim 57, wherein the controlsystem is configured to maintain the output fluid flow at a constanttemperature, including during the first and second discharge periods.

74. The thermal energy storage system of claim 57, wherein the controlsystem is configured to maintain the output fluid flow according to aspecified, non-constant temperature profile.

75. The thermal energy storage system of claim 64, wherein the controlsystem is configured to use the bypass fluid flow to cool the first andsecond assemblages during a charging period.

Alternate discharging below delivery temperature.

76. A thermal energy storage system configured to produce an outputfluid flow, the thermal energy storage system comprising:

-   -   a first assemblage of first thermal storage blocks and a second        assemblage of second thermal storage blocks, the first and        second thermal storage blocks configured to store thermal        energy; and    -   a control system configured to:        -   direct fluid flows during a first discharge period to            perform a first discharge operation in which the first            assemblage, but not the second assemblage, is discharged            below a delivery temperature of the output fluid flow; and        -   direct fluid flows during a second, successive discharge            period to perform a second discharge operation in which the            second assemblage, but not the first assemblage, is            discharged below the delivery temperature.

77. The thermal energy storage system of claim 76, wherein the controlsystem is configured to control an inlet valve configured to admit abypass fluid flow that bypasses the first and second assemblages duringdischarge periods, the bypass fluid flow having a bypass temperaturethat is less than the delivery temperature.

78. The thermal energy storage system of claim 77, wherein the controlsystem is configured to:

-   -   perform the first discharge operation such that the first        assemblage is discharged to a first discharge temperature that        is closer to the bypass temperature than to the delivery        temperature; and    -   perform the second discharge operation such that the second        assemblage is discharged to a second discharge temperature that        is closer to the bypass temperature than to the delivery        temperature.

79. The thermal energy storage system of claim 77, wherein the controlsystem is configured to:

-   -   perform the first discharge operation such that the first        assemblage is discharged to a first discharge temperature that        is closer to the bypass temperature than to a midpoint        temperature midway between the delivery temperature and the        bypass temperature; and    -   perform the second discharge operation such that the second        assemblage is discharged to a second discharge temperature that        is closer to the bypass temperature than to the midpoint        temperature.

80. The thermal energy storage system of claim 77, wherein the controlsystem is configured to:

-   -   perform the first discharge period such that the first        assemblage is discharged to a first discharge temperature that        is approximately equal to the bypass temperature; and    -   perform the second discharge period such that the second        assemblage is discharged to a second discharge temperature that        is approximately equal to the bypass temperature.

81. The thermal energy storage system of claim 78, wherein the controlsystem is configured to cause the first and second discharge operationsto be performed alternately in successive discharge periods.

82. The thermal energy storage system of claim 78, wherein the thermalenergy storage system is configured to produce the output fluid flowaccording to a non-constant temperature profile.

83. The thermal energy storage system of claim 78, wherein the controlsystem is configured to:

-   -   perform the first discharge operation by discharging the first        assemblage below the delivery temperature, and then initiating        fluid flow to the first assemblage in a trickle mode; and    -   perform the second discharge operation by discharging the second        assemblage below the delivery temperature, and then initiating        fluid flow to the second assemblage in the trickle mode.

Preventing thermal runaway by discharge operation.

84. A thermal energy storage system, comprising:

-   -   a first assemblage of first thermal storage blocks and a second        assemblage of second thermal storage blocks, the first and        second thermal storage blocks configured to store thermal        energy; and    -   a control system configured to:        -   direct fluid flows to the first and second assemblages to            produce an output fluid flow;        -   during a first discharge period, perform a first discharge            operation by discharging the first assemblage sufficiently            to prevent thermal runaway while discharging the second            assemblage to at or above a delivery temperature of the            output fluid flow; and        -   during a second, successive discharge period, perform a            second discharge operation by discharging the second            assemblage sufficiently to prevent thermal runaway while            discharging the first assemblage to at or above the delivery            temperature.

85. The thermal energy storage system of claim 84, wherein the controlsystem is configured to:

perform the first discharge operation by initiating discharge of thefirst assemblage at a beginning of the first discharge period andinitiating discharge of the second assemblage after a first dischargetemperature of a first fluid flow produced by the first assemblage dropsbelow the delivery temperature; and

perform the second discharge operation by initiating discharge of thesecond assemblage at a beginning of the second discharge period andinitiating discharge of the first assemblage after a second dischargetemperature of a second fluid flow produced by the second assemblagedrops below the delivery temperature.

86. The thermal energy storage system of claim 85, wherein the controlsystem is configured to cause the first and second discharge operationsto be performed alternately in successive discharge periods.

87. The thermal energy storage system of claim 85, wherein the controlsystem is configured to perform the first and second dischargeoperations by initiating a fluid flow to a given assemblage in a tricklemode after discharging the given assemblage to prevent thermal runaway.

Deep discharge with bypass fluid flow during first and second dischargeperiods.

88. A thermal energy storage system configured to produce an outputfluid flow, the thermal energy storage system comprising:

-   -   a first assemblage of first thermal storage blocks and a second        assemblage of second thermal storage blocks, the first and        second thermal storage blocks configured to store thermal        energy; and    -   a control system configured to:        -   cause, during a first portion of a first discharge period, a            first fluid flow produced from the first assemblage to be            mixed with a bypass fluid flow that bypasses the first and            second assemblages;        -   cause, during a second, subsequent portion of the first            discharge period, the first fluid flow to be mixed with a            second fluid flow produced from the second assemblage, such            that the first assemblage, but not the second assemblage, is            deeply discharged during the first discharge period;        -   cause, during a first portion of a second discharge period,            the second fluid flow to be mixed with the bypass fluid            flow; and        -   cause, during a second, subsequent portion of the second            discharge period, the second fluid flow to be mixed with the            first fluid flow such that the second assemblage, but not            the first assemblage, is deeply discharged during the second            discharge period.

89. The thermal energy storage system of claim 88, wherein the controlsystem is configured to alternate, in successive discharge periods,between:

-   -   deeply discharging the first assemblage but not the second        assemblage; and    -   deeply discharging the second assemblage but not the first        assemblage.

90. The thermal energy storage system of claim 89, wherein the controlsystem is configured to initiate a fluid flow to a given one of thefirst and second assemblage in a trickle mode after deeply dischargingthe given assemblage.

Method of deep discharge.

91. A method, comprising:

receiving, by a thermal energy storage system that includes a firstassemblage of first thermal storage blocks and a second assemblage ofsecond thermal storage blocks, input energy from a renewable energysource;

-   -   using, by the thermal energy storage system, the input energy to        create thermal energy that is stored in the first and second        thermal storage blocks;    -   directing, by the thermal energy storage system, fluid flows to        create an output fluid flow that is continuous over one or more        periods of unavailability of the renewable energy source by:

performing, in a first discharge period, a first discharge operationthat deeply discharges the first assemblage, but not the secondassemblage; and

performing, in a second discharge period, a second discharge operationthat deeply discharges the second assemblage, but not the firstassemblage.

92. The method of claim 91, wherein the fluid flows include a first flowproduced from the first assemblage, a second flow produced from thesecond assemblage, and a bypass flow produced that bypasses the firstand second assemblages during discharge periods, the bypass flow havinga bypass temperature that is lower than a delivery temperature of theoutput fluid flow.

93. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages includes discharging to a dischargetemperature that is closer to the bypass temperature than the deliverytemperature.

94. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages includes discharging to a dischargetemperature that is closer to the bypass temperature than to a midpointtemperature midway between the delivery temperature and the bypasstemperature.

95. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages includes discharging to a dischargetemperature that is approximately equal to the bypass temperature.

96. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages during a given discharge periodincludes:

initiating discharge of the given assemblage at a beginning of the givendischarge period; and

initiating discharge of the other one of the first and secondassemblages after a discharge temperature of a given fluid flow producedby the given assemblage drops below the delivery temperature; and

continuing discharge of the given assemblage after initiating dischargeof the other assemblage.

97. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages constitutes discharging the givenassemblage to a discharge temperature that is no higher than 25° C.above than the bypass temperature.

98. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages constitutes discharging the givenassemblage to a discharge temperature that is no higher than 50° C.above the bypass temperature.

99. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages constitutes discharging the givenassemblage to a discharge temperature that is no higher than 75° C.above than the bypass temperature.

100. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages constitutes discharging the givenassemblage to a discharge temperature that is no higher than 100° C.above than the bypass temperature.

101. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages constitutes discharging the givenassemblage to a discharge temperature that is no higher than 150° C.above than the bypass temperature.

102. The method of claim 92, wherein deeply discharging a given one ofthe first and second assemblages constitutes discharging the givenassemblage to a discharge temperature that is no higher than 200° C.above than the bypass temperature.

103. The method of claim 93, wherein performing the first dischargeoperation includes discharging the second assemblage to the deliverytemperature, and wherein performing the second discharge operationincludes discharging the first assemblage to the delivery temperature.

104. The method of claim 93, wherein performing the first dischargeoperation includes discharging the second assemblage to a first buffertemperature above the delivery temperature, and wherein performing thesecond discharge operation includes discharging the first assemblage toa second buffer temperature that is above the delivery temperature.

105. The method of claim 93, wherein performing the first dischargeoperation includes initiating fluid flow to the first assemblage in atrickle mode after deeply discharging the first assemblage, and whereinperforming the second discharge operation includes initiating fluid flowto the second assemblage in the trickle mode after deeply dischargingthe second assemblage.

106. The method of claim 105, wherein fluid flow in the trickle mode fora given assemblage is greater than 0% and no more than 10% of a maximumfluid flow for the given assemblage.

107. The method of claim 92, further comprising changing flow rates forthe first flow, the second flow, and the bypass flow to account for achange in the delivery temperature.

108. The method of claim 92, further comprising using the bypass flow tocool the first and second assemblages at a latter portion of a chargingperiod.

109. The method of claim 93, further comprising:

-   -   alternating, in successive discharge periods, between performing        the first discharge operation and the second discharge        operation.

Method with discharge temperature closer to bypass temperature than todelivery temperature.

110. A method, comprising:

receiving, by a thermal energy storage system that includes a firstassemblage of first thermal storage blocks and a second assemblage ofsecond thermal storage blocks, input energy from a renewable energysource;

-   -   using, by the thermal energy storage system, the input energy to        create thermal energy that is stored in the first and second        thermal storage blocks;    -   directing, by the thermal energy storage system, fluid flows to        create an output fluid flow, the fluid flows including a first        fluid flow produced from the first assemblage, a second fluid        flow produced from the second assemblage, and a bypass fluid        flow that bypasses the first and second assemblages during        discharge periods, the bypass fluid flow having a bypass        temperature that is lower than a delivery temperature of the        output fluid flow;    -   discharging, during a first discharge period, the first        assemblage, but not the second assemblage, to a first discharge        temperature that is closer to the bypass temperature than to the        delivery temperature; and

discharging, during a second discharge period, the second assemblage,but not the first assemblage, to a second discharge temperature that iscloser to the bypass temperature than the delivery temperature.

111. The method of claim 110, wherein the first and second dischargetemperatures are closer to the bypass temperature than to a temperaturemidpoint that is midway between the bypass temperature and the deliverytemperature.

112. The method of claim 110, wherein the first and second dischargetemperatures are approximately equal to the bypass temperature.

113. The method of claim 110, wherein discharging the first assemblageduring the first discharge period includes initiating fluid flow to thefirst assemblage in a trickle mode after discharging the firstassemblage to the first discharge temperature; and

wherein discharging the second assemblage during the second dischargeperiod includes initiating fluid flow to the second assemblage in thetrickle mode after discharging the second assemblage to the seconddischarge temperature.

Method with discharge to reduce thermal runaway.

114. A method, comprising:

receiving, by a thermal energy storage system that includes a firstassemblage of first thermal storage blocks and a second assemblage ofsecond thermal storage blocks, input energy from a renewable energysource;

-   -   using, by the thermal energy storage system, the input energy to        create thermal energy that is stored in the first and second        thermal storage blocks;    -   controlling fluid flows to the first and second assemblages to        produce an output fluid flow at temperatures within a selected        temperature range, wherein the controlling causes:        -   during a first discharge period, discharging the first            assemblage in a manner sufficient to reduce thermal runaway            in the first thermal storage blocks while discharging the            second assemblage to a temperature at or above the selected            temperature range; and        -   during a second, successive discharge period, discharging            the second assemblage in a manner sufficient to reduce            thermal runaway in the second thermal storage blocks while            discharging the first assemblage to a temperature at or            above the selected temperature range.

115. The method of claim 114, wherein discharging the first assemblageduring the first discharge period includes initiating fluid flow to thefirst assemblage in a trickle mode after deeply discharging the firstassemblage, and wherein discharging the second assemblage during thesecond discharge period includes initiating fluid flow to the secondassemblage in the trickle mode after deeply discharging the secondassemblage.

116. The method of claim 114, wherein discharging the first and secondassemblages to reduce thermal runaway is performed based on measuredthermal data for the first and second assemblages.

117. The method of claim 114, wherein discharging the first and secondassemblages to reduce thermal runaway is performed based on a modelingof thermal data for the first and second assemblages.

System with a given stack discharge temperature closer to bypasstemperature than to delivery temperature and lower than other stack'sdischarge temperature.

118. A thermal energy storage system configured to produce an outputfluid flow having a delivery temperature, the thermal energy storagesystem comprising:

-   -   a first assemblage of first thermal storage blocks and a second        assemblage of second thermal storage blocks, the first and        second thermal storage blocks configured to store thermal        energy; and    -   an inlet valve;    -   a control system configured to:        -   cause the inlet valve to admit a bypass fluid flow that            bypasses the first and second assemblages, the bypass fluid            flow having a bypass temperature that is lower than the            delivery temperature;        -   during a first discharge period, perform a first discharge            operation in which the first assemblage is discharged to a            first discharge temperature that is (a) closer to the bypass            temperature than to the delivery temperature, and (b) lower            than a second discharge temperature of the second            assemblage; and        -   during a second, successive discharge period, perform a            second discharge operation in which the second assemblage is            discharged to a third discharge temperature that is (a)            closer to the bypass temperature than to the delivery            temperature and (b) lower than a fourth discharge            temperature of the first assemblage.

119. The thermal energy storage system of claim 118, wherein the controlsystem is configured to alternate between performing the first dischargeoperation and the second discharge operation in successive dischargeperiods.

120. The thermal energy storage system of claim 119, wherein the secondand fourth discharge temperatures of the first and second dischargeperiods, respectively, correspond to the delivery temperature.

121. The thermal energy storage system of claim 119, wherein the seconddischarge temperature corresponds to a first buffer temperature abovethe specified delivery temperature, and wherein the fourth dischargetemperature corresponds to a second buffer temperature above thespecified delivery temperature.

122. The thermal energy storage system of claim 121, wherein:

the first discharge operation further includes maintaining a firsttrickle fluid flow to the first assemblage after discharging the firstassemblage to the first discharge temperature; and

the second discharge operation further includes maintaining a secondtrickle fluid flow to the second assemblage after discharging the secondassemblage to the second discharge temperature.

123. The thermal energy storage system of claim 122, wherein:

the first trickle fluid flow is less than 10% of a maximum fluid flowfor the first assemblage; and

the second trickle fluid flow is less than 10% of a maximum fluid flowfor the second assemblage.

124. The thermal energy storage system of claim 118, wherein the firstdischarge temperature and the second discharge temperature are closer tothe bypass temperature than to a temperature midpoint that is midwaybetween the bypass temperature and the delivery temperature.

System with deep discharge to reduce temperature nonuniformities.

125. A thermal energy storage system, comprising:

-   -   one or more assemblages of thermal storage blocks, wherein each        assemblage is configured to store heat generated from received        electrical energy as thermal energy; and    -   a control system configured to:    -   direct fluid flows to the one or more assemblages to produce an        output fluid flow, and    -   cause each of the one or more assemblages to be periodically        deeply discharged to reduce temperature nonuniformities within        the one or more assemblages.

126. The thermal energy storage system of claim 125, wherein the one ormore assemblages is made up of a single assemblage, and wherein thecontrol system is configured to cause the single assemblage toperiodically be deeply discharged on an as-needed basis.

127. The thermal energy storage system of claim 125, wherein the one ormore assemblages is made up of a single assemblage, and wherein thecontrol system is configured to cause the single assemblage toperiodically be deeply discharged at regularly occurring intervals.

128. The thermal energy storage system of claim 125, wherein the one ormore assemblages are a plurality of N assemblages, and wherein thecontrol system is configured to cause each of the N assemblages to bedeeply discharged once every N discharge periods.

129. The thermal energy storage system of claim 125, wherein the outputfluid flow has a specified temperature profile, wherein the one or moreassemblages are a plurality of N assemblages, and wherein the controlsystem is configured to cause each of the N assemblages to be deeplydischarged at least once every N discharge periods and partiallydischarged to a current value of the specified temperature profile atleast once every N discharge periods.

130. The thermal energy storage system of claim 125, wherein the one ormore assemblages includes a first assemblage and a second assemblage,and wherein the control system is configured to alternate, in successivedischarge periods, between:

-   -   deeply discharging the first assemblage and partially        discharging the second assemblage to a current value of the        specified temperature profile; and    -   deeply discharging the second assemblage and partially        discharging the first assemblage to the current value of the        specified temperature profile.

131. The thermal energy storage system of claim 125, wherein the controlsystem is configured to open an inlet valve to admit a bypass fluid flowthat is mixed with other fluid flows to produce the output fluid flow,the output fluid flow having a delivery temperature and the bypass fluidflow having a bypass temperature, and wherein the one or moreassemblages are deeply discharged to be closer to the bypass temperaturethan to the delivery temperature.

132. The thermal energy storage system of claim 125, wherein the controlsystem is configured to provide supply a trickle fluid flow to a givenassemblage after the given assemblage has been deeply discharged.

Method with deep discharge to reduce temperature nonuniformities.

133. A method, comprising:

-   -   receiving, at a thermal storage structure, input electrical        energy from a renewable energy source;    -   using, by thermal storage structure, the received input        electrical energy to heat heating elements within one or more        assemblages of thermal storage blocks;    -   directing fluid flows to the one or more assemblages to produce        an output fluid flow having a delivery temperature; and    -   deeply discharging each of the one or more assemblages        periodically to reduce temperature nonuniformities.

134. The method of claim 133, wherein the one or more assemblagescomprise a plurality of N assemblages, and wherein each of the Nassemblages is deeply discharged once every N discharge periods.

135. The method of claim 134, wherein each of the N assemblages isdeeply discharged at least once every N discharge periods and partiallydischarged at least once every N discharge periods.

136. The method of claim 133, wherein the one or more assemblagesinclude a first assemblage and a second assemblage, and wherein themethod further comprises alternating, in successive discharge periods,between:

-   -   deeply discharging the first assemblage and partially        discharging the second assemblage; and    -   deeply discharging the second assemblage and partially        discharging the first assemblage.

137. The method of claim 136, wherein the partially dischargingconstitutes discharging to the delivery temperature of the output fluidflow.

138. The method of claim 133, wherein the fluid flows include flows fromeach of the one or more assemblages and a bypass fluid flow from aninlet valve that bypasses the one or more assemblages during dischargeperiods, the bypass fluid flow having a bypass temperature that is lowerthan the delivery temperature.

139. The method of claim 138, wherein the one or more assemblages aredeeply discharged to discharge temperatures that are closer to thebypass temperature than to the delivery temperature.

140. The method of claim 138, wherein the one or more assemblages aredeeply discharged to discharge temperatures that are closer to thebypass temperature than to a temperature midpoint that is midway betweenthe bypass temperature and the delivery temperature.

141. The method of claim 136, further comprising causing a trickle fluidflow to be provided to a given assemblage during a discharge periodafter the given assemblage has been deeply discharged.

142. The method of claim 138, wherein deeply discharging a givenassemblage constitutes discharging to temperatures that are no higherthan 25° C. above than the bypass temperature.

143. The method of claim 138, wherein deeply discharging a givenassemblage constitutes discharging to temperatures that are no higherthan 50° C. above than the bypass temperature.

144. The method of claim 138, wherein deeply discharging a givenassemblage constitutes discharging to temperatures that are no higherthan 75° C. above than the bypass temperature.

145. The method of claim 138, wherein deeply discharging a givenassemblage constitutes discharging to temperatures that are no higherthan 100° C. above than the bypass temperature.

146. The method of claim 138, wherein deeply discharging a givenassemblage constitutes discharging to temperatures that are no higherthan 150° C. above than the bypass temperature.

147. The method of claim 138, wherein deeply discharging a givenassemblage constitutes discharging to temperatures that are no higherthan 200° C. above than the bypass temperature.

Thermal energy storage system including steam generator with feedbackcontrol. The system allows control of the temperature and flow rate ofheated fluid, and hence the amount of heat delivered to the steamgenerator, allowing the steam quality to be precisely controlled usingfeedback.

148. A thermal energy storage system, comprising:

-   -   a storage medium (14, 209) configured to store thermal energy        obtained using an input energy supply from an energy source (2,        201);    -   a fluid movement device (213, 4223) configured to move fluid        through the storage medium and discharge the stored thermal        energy from the storage medium into the fluid;    -   a once-through steam generator (1419) configured to receive the        fluid (20) from the storage medium and to exchange heat from the        fluid with water from a water source to produce steam; and    -   a control system (15, 1502) configured to        -   measure a value indicating steam quality of the steam; and        -   based on the measured value, control a flow rate of the            fluid received by the steam generator.

149. The thermal energy storage system of claim 148, further comprisingone or more instruments configured to detect the value indicating steamquality of the steam, and wherein the control system is configured tomeasure the value by interfacing with the instruments.

150. The thermal energy storage system of claim 148, wherein the one ormore instruments are configured to detect an inlet flow velocity ofwater at an inlet of the steam generator and an outlet flow velocity ofsteam at an outlet of the steam generator.

151. The thermal energy storage system of claim 149, further comprisinga vapor-liquid separator configured to separate the steam into a liquidcomponent and a vapor component, and wherein the one or more instrumentsare configured to detect a liquid component heat value and a vaporcomponent heat value.

152. The thermal energy storage system of claim 148, wherein the controlsystem is configured to measure an inlet flow velocity of water at aninlet of the steam generator and an outlet flow velocity of steam at anoutlet of the steam generator.

153. The thermal energy storage system of claim 148, further comprisinga vapor-liquid separator configured to separate the steam into a liquidcomponent and a vapor component, and wherein the control system isconfigured to measure a liquid component heat value and a vaporcomponent heat value.

154. The thermal energy storage system of claim 148, further comprisingan adjustable fluid restricting device, and wherein the control systemis configured to send control signals to the adjustable fluidrestricting device based on the measured value.

155. The thermal energy storage system of claim 154, wherein theadjustable fluid restricting device comprises a louver.

156. The thermal energy storage system of claim 154, wherein theadjustable fluid restricting device comprises a valve.

157. The thermal energy storage system of claim 148, wherein, if themeasured value of steam quality indicates a decrease in steam quality,the control system is configured to increase a flow rate of the fluid.

The control of flow rate and temperature provided by the thermal energystorage system allows control of output steam parameters using flowrate.

158. The thermal energy storage system of claim 148, wherein the controlsystem is configured to:

-   -   prior to measuring the value indicating steam quality, receive a        target steam parameter;    -   obtain an inlet water temperature at an inlet of the steam        generator; and    -   based on the target steam parameter and the inlet temperature,        determine an initial flow rate for the fluid received by the        steam generator.

159. The thermal energy storage system of claim 158, wherein the targetsteam parameter comprises a target steam quality.

160. The thermal energy storage system of claim 158, wherein the targetsteam parameter comprises a target steam delivery rate.

161. The thermal energy storage system of claim 158, wherein thecontroller is configured to obtain the inlet water temperature bymeasuring the inlet water temperature.

162. The thermal energy storage system of claim 148, wherein the steamgenerator comprises a once-through steam generator.

163. The thermal energy storage system of claim 148, wherein the energysource is a source of intermittent availability.

164. The thermal energy storage system of claim 148, wherein the energysource comprises a solar energy source.

165. The thermal energy storage system of claim 148, wherein the energysource comprises a wind-powered energy source.

Thermal energy storage system method of operation controls thetemperature and flow rate of heated fluid, and therefore the amount ofheat delivered to the steam generator, allowing the steam quality to beprecisely controlled using feedback.

166. A method of storing and delivering thermal energy, comprising:

-   -   receiving input energy from an energy source (2, 201);    -   storing thermal energy obtained using the input energy in a        storage medium (14, 209);    -   moving fluid through the storage medium to heat the fluid;    -   delivering the heated fluid (20) to a once-through steam        generator (1419) configured to generate steam by exchanging heat        from the fluid with water from a water source;    -   obtaining a steam quality value of the steam; and    -   based on the steam quality value, providing a feedback signal        for adjusting a rate of delivering the heated fluid to the steam        generator.

167. The method of claim 166, wherein obtaining the steam quality valuecomprises:

-   -   separating the steam into liquid phase and vapor phase        components; and    -   independently monitoring heat of the liquid phase and vapor        phase components.

168. The method of claim 166, wherein obtaining the steam quality valuecomprises:

-   -   measuring an outlet flow velocity of the steam at an outlet of        the steam generator; and    -   measuring an inlet flow velocity of the water at an inlet of the        steam generator.

169. The method of claim 166, wherein providing a feedback signalcomprises providing the signal to a controllable element is configuredto adjust a flow rate of the fluid through the storage medium.

170. The method of claim 169, wherein the controllable element comprisesa louver.

171. The method of claim 169, wherein the controllable element comprisesa valve.

Control of flow rate and temperature provides control of output steamparameters on a feedforward basis.

172. The method of claim 166, further comprising, prior to obtaining thesteam quality value of the steam:

-   -   receiving a target parameter for the steam;    -   obtaining an inlet water temperature at an inlet of the steam        generator; and    -   based on the target steam parameter and the inlet temperature,        determining an initial rate for delivering the heated fluid to        the steam generator.

173. The method of claim 172, wherein receiving a target parametercomprises receiving a target steam quality.

174. The method of claim 172, wherein receiving a target parametercomprises receiving a target steam delivery rate.

175. The method of claim 172, wherein obtaining an inlet watertemperature comprises measuring the inlet water temperature.

Control of steam quality using flow rate from thermal storage.

176. The method of claim 166, wherein the steam generator comprises aonce-through steam generator.

177. The method of claim 166, wherein the energy source is a source ofintermittent availability.

178. The method of claim 166, wherein the energy source comprises asolar energy source.

179. The method of claim 166, wherein the energy source comprises awind-powered energy source.

System configured to control flow rate and temperature to control outputsteam parameters on a feed forward basis.

180. A thermal energy storage system, comprising:

-   -   a storage medium (14, 209) configured to store thermal energy        obtained using an input energy supply from an energy source (2,        201);    -   a fluid movement device (213, 4223) configured to move fluid        through the storage medium and discharge the stored thermal        energy from the storage medium into the fluid;    -   a steam generator (1419) configured to receive the fluid (20)        from the storage medium and to exchange heat from the fluid with        water from a water source to produce steam; and    -   a control system (15, 1502) configured to        -   receive a target steam parameter,        -   obtain an inlet water temperature at an inlet of the steam            generator; and        -   based on the target steam parameter and the inlet            temperature, determine an initial flow rate for the fluid            received by the steam generator.

181. The thermal energy storage system of claim 180, wherein the targetsteam parameter comprises a target steam quality.

182. The thermal energy storage system of claim 180, wherein the targetsteam parameter comprises a target steam delivery rate.

183. The thermal energy storage system of claim 180, wherein thecontroller is configured to obtain the inlet water temperature bymeasuring the inlet water temperature.

System configured control temperature and flow rate of heated fluid, andtherefore the amount of heat delivered to the steam generator, allowingthe steam quality to be precisely controlled using feedback.

184. The thermal energy storage system of claim 180, wherein the controlsystem is configured to:

-   -   measure a value indicating steam quality of the steam; and    -   based on the measured value, control an ongoing flow rate of the        fluid received by the steam generator.

185. The thermal energy storage system of claim 184, further comprisingone or more instruments configured to detect the value indicating steamquality of the steam, and wherein the control system is configured tomeasure the value by interfacing with the instruments.

186. The thermal energy storage system of claim 185, wherein the one ormore instruments are configured to detect an inlet flow velocity ofwater at an inlet of the steam generator and an outlet flow velocity ofsteam at an outlet of the steam generator.

187. The thermal energy storage system of claim 185, further comprisinga vapor-liquid separator configured to separate the steam into a liquidcomponent and a vapor component, and wherein the control system isconfigured to measure a liquid component heat value and a vaporcomponent heat value.

188. The thermal energy storage system of claim 184, further comprisingan adjustable fluid restricting device, and wherein the control systemis configured to send a control signal to the adjustable fluidrestricting device based on the measured value.

189. The thermal energy storage system of claim 188, wherein theadjustable fluid restricting device comprises a louver.

190. The thermal energy storage system of claim 188, wherein theadjustable fluid restricting device comprises a valve.

191. The thermal energy storage system of claim 180, wherein the steamgenerator comprises a once-through steam generator.

192. The thermal energy storage system of claim 180, wherein the energysource is a source of intermittent availability.

193. The thermal energy storage system of claim 180, wherein the energysource comprises a solar energy source.

194. The thermal energy storage system of claim 180, wherein the energysource comprises a wind-powered energy source.

195. A method of storing and delivering thermal energy, comprising:

-   -   receiving input energy from an energy source (2, 201);    -   storing thermal energy obtained using the input energy in a        storage medium (14, 209);    -   moving fluid through the storage medium to heat the fluid;    -   delivering the heated fluid (20) to steam generator (1419)        configured to generate steam by exchanging heat from the fluid        with water from a water source;

receiving a target parameter for the steam;

-   -   obtaining an inlet water temperature at an inlet of the steam        generator; and    -   based on the target steam parameter and the inlet temperature,        determining an initial rate for delivering the heated fluid to        the steam generator.

196. The method of claim 195, wherein receiving a target parametercomprises receiving a target steam quality.

197. The method of claim 195, wherein receiving a target parametercomprises receiving a target steam delivery rate.

198. The method of claim 195, wherein obtaining the inlet watertemperature comprises measuring the inlet water temperature.

199. The method of claim 195, further comprising, subsequent todetermining the initial rate:

-   -   obtaining a steam quality value of the steam; and    -   based on the steam quality value, providing a feedback signal        for adjusting an ongoing rate of delivering the heated fluid to        the steam generator.

200. The method of claim 199, wherein obtaining a steam quality valuecomprises:

separating the steam into liquid phase and vapor phase components; and

-   -   independently monitoring heat of the liquid phase and vapor        phase components.

201. The method of claim 199, wherein obtaining a steam quality valuecomprises:

-   -   measuring an outlet flow velocity of the steam at an outlet of        the steam generator; and    -   measuring an inlet flow velocity of the water at an inlet of the        steam generator.

202. The method of claim 199, wherein providing a feedback signalcomprises providing the signal to a controllable element configured toadjust a flow rate of the fluid through the storage medium.

203. The method of claim 202, wherein the controllable element comprisesa louver.

204. The method of claim 202, wherein the controllable element comprisesa valve.

205. The method of claim 195, wherein the steam generator comprises aonce-through steam generator.

206. The method of claim 195, wherein the energy source is a source ofintermittent availability.

207. The method of claim 195, wherein the energy source comprises asolar energy source.

208. The method of claim 195, wherein the energy source comprises awind-powered energy source.

System combining the outputs of two thermal storage mediums whileseparately controlling flow through them allows a specified outputproperty of the delivered fluid to be maintained.

209. A thermal energy storage system, comprising:

a first storage medium (14, 209) configured to store thermal energyobtained using an input energy supply from an energy source (2, 201);

a second storage medium (14, 209) configured to store thermal energyobtained using the input energy supply;

a fluid movement device (213, 4223) configured to move fluid through thefirst and second storage mediums to heat the fluid and provide theheated fluid (20) to a load system (22); and

a control system (15, 1502) configured to separately control movement ofthe fluid through the first and second storage mediums to maintain aspecified property of the heated fluid.

210. The thermal energy storage system of claim 209, wherein thespecified property comprises a temperature of the heated fluid.

211. The thermal energy storage system of claim 209, wherein thespecified property comprises a thermal energy of the heated fluid.

212. The thermal energy storage system of claim 209, wherein thespecified property comprises a flow rate of the heated fluid.

213. The thermal energy storage system of claim 209, further comprising:

a first adjustable fluid restricting device configured to adjust a rateof fluid flow through the first storage medium; and

a second adjustable fluid restricting device configured to adjust a rateof fluid flow through the second storage medium.

214. The thermal energy storage system of claim 213, wherein the controlsystem is configured to separately send control signals to the first andsecond adjustable fluid restricting devices.

215. The thermal energy storage system of claim 213, wherein the firstand second adjustable fluid restricting devices comprise louvers.

216. The thermal energy storage system of claim 213, wherein the firstand second adjustable fluid restricting devices comprise valves.

217. The thermal energy storage system of claim 209, wherein the loadsystem comprises a steam generator.

218. The thermal energy storage system of claim 217, wherein the steamgenerator comprises a once-through steam generator.

219. The thermal energy storage system of claim 209, wherein the loadsystem comprises an electrolysis reactor.

220. The thermal energy storage system of claim 209, wherein the loadsystem comprises a material activation system.

221. The thermal energy storage system of claim 220, wherein thematerial activation system comprises a calciner.

222. The thermal energy storage system of claim 209, wherein the energysource is a source of intermittent availability.

223. The thermal energy storage system of claim 209, wherein the energysource comprises a solar energy source.

224. The thermal energy storage system of claim 209, wherein the energysource comprises a wind-powered energy source.

Method combining the outputs of two thermal storage mediums whileseparately controlling flow through them allows a specified outputproperty of the delivered fluid to be maintained.

225. A method of storing and delivering thermal energy, comprising

receiving input energy from an energy source (2, 201);

storing thermal energy obtained using the input energy in a firststorage medium (14, 209) and a second storage medium (14, 209);

-   -   moving fluid through the first and second storage mediums to        heat the fluid;    -   delivering the heated fluid (20) to a load system (22); and

separately controlling flow rates of the fluid through the first andsecond storage mediums to maintain a specified property of the heatedfluid.

226. The method of claim 225, wherein the specified property comprises atemperature of the heated fluid.

227. The method of claim 225, wherein the specified property comprises athermal energy of the heated fluid.

228. The method of claim 225, wherein the specified property comprises aflow rate of the heated fluid.

229. The method of claim 225, wherein separately controlling flow ratesof the fluid through the first and second storage mediums comprisessending separate control signals to first and second adjustable fluidrestricting devices associated with the first and second storagemediums, respectively.

230. The method of claim 229, wherein the first and second adjustablefluid restricting devices comprise louvers.

231. The method of claim 229, wherein the first and second adjustablefluid restricting devices comprise valves.

232. The method of claim 225, wherein the load system comprises a steamgenerator.

233. The method of claim 232, wherein the steam generator comprises aonce-through steam generator.

234. The method of claim 225, wherein the load system comprises anelectrolysis system.

235. The method of claim 234, wherein the load system comprises amaterial activation system.

236. The method of claim 235, wherein the material activation systemcomprises a calciner.

237. The method of claim 225, wherein the energy source is a source ofintermittent availability.

238. The method of claim 225, wherein the energy source comprises asolar energy source.

239. The method of claim 225, wherein the energy source comprises awind-powered energy source.

Use of forecast information regarding energy source availability allowsthe system to adjust its received energy, helping to maintain consistentoperation.

240. A thermal energy storage system, comprising:

a storage medium (14, 209) configured to store thermal energy obtainedusing input energy from an energy source (2, 201);

a fluid movement device (213, 4223) configured to move fluid through thestorage medium to heat the fluid and provide the heated fluid (20) to aload system (22); and

-   -   a control system (15, 1502) configured to:        -   receive forecast information regarding availability of the            energy source; and        -   based on the forecast information, control a heated fluid            discharge rate.

241. The thermal energy storage system of claim 240, wherein the controlsystem is configured to communicate with an energy source controlsystem.

242. The thermal energy storage system of claim 241, wherein the controlsystem is configured to send to the energy source control system arequest or instruction to reduce an amount of input energy supplied bythe source when the forecast information indicates an increase inavailability of the energy source.

243. The thermal energy storage system of claim 241, wherein the controlsystem is configured to send to the energy source control system arequest or instruction to transfer excess energy to an available powergrid when the forecast information indicates an increase in availabilityof the energy source.

244. The thermal energy storage system of claim 241, wherein the controlsystem is configured to send to the energy source control system arequest or instruction to curtail a portion of the energy source'sproduction when the forecast information indicates an increase inavailability of the energy source.

245. The thermal energy storage system of claim 240, wherein the controlsystem is configured to connect to an available power grid to obtainadditional input energy when the forecast information indicates adecrease in availability of the energy source.

246. The thermal energy storage system of claim 240, wherein the controlsystem is configured to connect to an alternate energy source when theforecast information indicates a decrease in availability of the energysource.

247. The thermal energy storage system of claim 240, wherein the controlsystem is configured to receive the forecast information from an energysource control system.

248. The thermal energy storage system of claim 240, wherein the controlsystem is configured to receive the forecast information from ananalytics system external to the control system.

249. The thermal energy storage system of claim 240, wherein the energysource is a source of intermittent availability.

250. The thermal energy storage system of claim 240, wherein the energysource comprises a solar energy source.

251. The thermal energy storage system of claim 240, wherein the energysource comprises a wind-powered energy source.

Use of forecast information regarding energy source availability allowsthe system to adjust its received energy, helping to maintain consistentoperation.

252. A method of storing and delivering thermal energy, comprising:

-   -   receiving input energy from an energy source (2, 201);    -   storing in a storage medium (14, 209) thermal energy obtained        using the input energy;    -   moving fluid through the storage medium to heat the fluid for        delivery to a load system (22);    -   receiving forecast information regarding availability of the        energy source; and    -   based on the forecast information, controlling a heated fluid        discharge rate.

253. The method of claim 252, wherein altering the amount of inputenergy comprises communicating with a control system for the energysource.

254. The method of claim 253, wherein communicating with the controlsystem for the energy source comprises sending a request or instructionto reduce an amount of input energy supplied by the source when theforecast information indicates an increase in availability of the energysource.

255. The method of claim 253, wherein communicating with the controlsystem for the energy source comprises sending a request or instructionto transfer excess energy to an available power grid when the forecastinformation indicates an increase in availability of the energy source.

256. The method of claim 253, wherein communicating with the controlsystem for the energy source comprises sending a request or instructionto curtail a portion of the energy source's production when the forecastinformation indicates an increase in availability of the energy source.

257. The method of claim 252, wherein altering the amount of inputenergy comprises connecting to an available power grid to obtainadditional input energy when the forecast information indicates adecrease in availability of the energy source.

258. The method of claim 252, wherein altering the amount of inputenergy comprises connecting to an alternate energy source when theforecast information indicates a decrease in availability of the energysource.

259. The method of claim 252, wherein receiving forecast informationcomprises receiving information from a control system of the energysource.

260. The method of claim 252, wherein receiving forecast informationcomprises receiving information from an analytics system.

261. The method of claim 250, wherein the energy source is a source ofintermittent availability.

262. The method of claim 252, wherein the energy source comprises asolar energy source and/or a wind-powered energy source.

Use of forecast information regarding energy source availability allowsthe system to adjust an operating parameter, which can help to maintainconsistent operation and improve system reliability and componentlifetime (e.g., when excess energy is available so that heating elementtemperatures can be reduced).

263. A thermal energy storage system, comprising:

a storage medium (14, 209) configured to store thermal energy obtainedusing input energy from an energy source (2, 201);

a fluid movement device configured to move fluid through the storagemedium to heat the fluid and provide the heated fluid (20) to a loadsystem (22); and

-   -   a control system (15, 1502) configured to        -   receive forecast information regarding availability of the            energy source, and    -   based on the forecast information, adjust an operating parameter        of the thermal energy storage system.

264. The thermal energy storage system of claim 263, wherein the inputenergy is electrical energy, and further comprising a heating elementconfigured to convert a portion of the input energy to a portion of thethermal energy.

Supercharging the thermal storage medium allows the specified outputtemperature or energy of the system to be maintained through a period oflower energy source availability.

265. The thermal energy storage system of claim 264, wherein the controlsystem is configured to operate the heating element at an increasedelectrical power level during a period of availability of the energysource, when the forecast information indicates an upcoming reduction inavailability of the energy source.

Reduced heater power level when power is expected to be available for alonger time than normal allows reliable output to be maintained whilereducing stress on the heating elements and storage medium.

266. The thermal energy storage system of claim 264, wherein the controlsystem is configured to operate the heating element at a decreasedelectrical power level during a period of availability of the energysource, when the forecast information indicates an upcoming increase inavailability of the energy source.

267. The thermal energy storage system of claim 263, further comprisingan auxiliary heater system configured to heat at least a portion of thefluid at a location outside of the storage medium, wherein the controlsystem is configured to direct excess input energy to the auxiliaryheater system during a period of energy availability.

When a high amount of input energy is forecast, using excess energy toheat the fluid using an auxiliary heater while reducing the thermalenergy in the storage medium may reduce wear and tear on the storagemedium and its heating elements.

268. The thermal energy storage system of claim 267, wherein theforecast information indicates an upcoming increase in availability ofthe energy source and the control system is configured to reduce anamount of thermal energy stored in the storage medium commensuratelywith an increase in thermal energy provided by the auxiliary heatersystem.

When a low amount of input energy is forecast, using the auxiliaryheater may allow a delay in when the thermal storage will need to bedischarged, which helps to provide continuous power during the low inputenergy period.

269. The thermal energy storage system of claim 267, wherein theforecast information indicates an upcoming decrease in availability ofthe energy source and the control system is configured to maintain orincrease an amount of thermal energy stored in the storage medium duringthe period of energy availability.

270. The thermal energy storage system of claim 267, wherein theauxiliary heater system comprises a heater positioned along a bypassline configured to convey a portion of the fluid to the load systemwithout passing the portion through the storage medium.

271. The thermal energy storage system of claim 267, wherein theauxiliary heater system comprises a heater positioned along an outletline between an outlet of the storage medium and an inlet of the loadsystem.

272. The thermal energy storage system of claim 263, wherein the controlsystem is configured to adjust a flow rate of the fluid through thestorage medium based on the forecast information.

273. The thermal energy storage system of claim 263, wherein the controlsystem is configured to reduce a flow rate of the fluid through thestorage medium when the forecast information indicates an upcomingdecrease in availability of the energy source.

274. The thermal energy storage system of claim 263, wherein the controlsystem is configured to receive the forecast information from an energysource control system.

275. The thermal energy storage system of claim 263, wherein the controlsystem is configured to receive the forecast information from ananalytics system external to the control system.

276. The thermal energy storage system of claim 263, wherein theforecast information relates to relative time periods of energy sourceavailability and unavailability.

277. The thermal energy storage system of claim 263, wherein theforecast information relates to a relative magnitude of energy availablefrom the energy source.

278. The thermal energy storage system of claim 263, wherein the energysource is a source of intermittent availability.

279. The thermal energy storage system of claim 263, wherein the energysource comprises a solar energy source.

280. The thermal energy storage system of claim 263, wherein the energysource comprises a wind-powered energy source.

Use of forecast information regarding energy source availability allowsthe system to adjust an operating parameter, which can help to maintainconsistent operation and in some cases improve system reliability andcomponent lifetime (e.g., when excess energy is available so thatheating element temperatures can be reduced).

281. A method of storing and delivering thermal energy, comprising:

-   -   receiving input energy from an energy source (2, 201);    -   storing in a storage medium (14, 209) thermal energy obtained        using the input energy;    -   moving fluid through the storage medium to heat the fluid for        delivery to a load system (22);    -   receiving forecast information regarding availability of the        energy source; and

based on the forecast information, adjusting an operating parameterassociated with moving the fluid through the storage medium.

Supercharging the thermal storage medium allows the specified outputtemperature or energy of the system to be maintained through a period oflower energy source availability.

282. The method of claim 281, wherein adjusting an operating parametercomprises, during a period of availability of the energy source when theforecast information indicates an upcoming reduction in availability ofthe energy source, operating at an increased electrical power level aheating element associated with the storage medium.

Reduced heater power level when a high amount or duration input energyis forecast to be available allows the same output to be maintainedwhile reducing stress on the heating element and storage medium.

283. The method of claim 281, wherein adjusting an operating parametercomprises, during a period of availability of the energy source when theforecast information indicates an upcoming increase in availability ofthe energy source, operating at a decreased electrical power level aheating element associated with the storage medium.

284. The method of claim 281, wherein adjusting an operating parametercomprises, during a period of energy source availability, directingexcess energy to an auxiliary heater system configured to heat at leasta portion of the fluid at a location outside of the storage medium.

When a high amount of input energy is forecast, using excess energy toheat the fluid using an auxiliary heater while reducing the thermalenergy in the storage medium may reduce wear and tear on the storagemedium and its heating elements.

285. The method of claim 284, wherein adjusting an operating parametercomprises, when the forecast indicates an upcoming increase inavailability of the energy source, reducing an amount of thermal energystored in the storage medium commensurately with an increase in thermalenergy provided by the auxiliary heater system.

When a low amount of input energy is forecast, using the auxiliaryheater may allow a delay in when the thermal storage will need to bedischarged, which helps to provide continuous power during the low inputenergy period.

286. The method of claim 284, wherein adjusting an operating parametercomprises, when the forecast indicates an upcoming decrease inavailability of the energy source, controlling a heated fluid dischargerate to maintain energy output over a determined period of time.

287. The method of claim 284, wherein the auxiliary heater systemcomprises a heater positioned along a bypass line configured to convey aportion of the fluid to the load system without passing the portionthrough the storage medium.

288. The method of claim 284, wherein the auxiliary heater systemcomprises a heater positioned along an outlet line between an outlet ofthe storage medium and an inlet of the load system.

289. The method of claim 281, wherein adjusting the operating parametercomprises adjusting a flow rate of the fluid through the storage mediumbased on the forecast information.

290. The method of claim 281, wherein adjusting the operating parametercomprises reducing a flow rate of the fluid through the storage mediumwhen the forecast information indicates an upcoming decrease inavailability of the energy source.

291. The method of claim 281, wherein receiving forecast informationcomprises receiving the forecast information from an energy sourcecontrol system.

292. The method of claim 281, wherein receiving forecast informationcomprises receiving the forecast information from an analytics system.

293. The method of claim 281, wherein the forecast information relatesto relative time periods of energy source availability andunavailability.

294. The method of claim 281, wherein the forecast information relatesto a relative magnitude of energy available from the energy source.

295. The method of claim 281, wherein the energy source is a source ofintermittent availability.

296. The method of claim 281, wherein the energy source comprises asolar energy source.

297. The method of claim 281, wherein the energy source comprises awind-powered energy source.

DC-DC Conversion Systems and Methods

DC-DC Conversion allows for a lower-loss method of power transmissionthan conventional AC power transfer due to smaller eddy currents andlower resistances in the system as the power generated by the generatorcircuits varies in time.

298. A thermal storage system, including:

a thermal storage medium (3111);

a heating element (3112) positioned to heat the thermal storage medium;and

a power transfer system (3103A-C, 3101, 3102), comprising:

a plurality of generator circuits (3103A-C) configured to generate aplurality of time-varying direct current (DC) voltages;

a first converter circuit (3101) that includes a plurality of firstconverter circuits (3203A-C), each first converter circuit including:

a first input circuit (3401) configured to receive one of thetime-varying DC voltages, and a first output circuit (3419) galvanicallyisolated from the input circuit and configured to generate a firstcorresponding DC voltage derived from the time-varying DC voltagereceived by the first input circuit, wherein the first converter circuitis configured to combine the first corresponding DC voltages of thefirst output circuits to generate a transmit voltage and drive atransmission line; and

a second converter circuit (3102) that includes a plurality of secondconverter circuits, each second converter circuit including:

a second input circuit (3401) configured to receive a portion of thetransmit voltage, and a second output circuit (3419) galvanicallyisolated from the second input circuit and configured to generate asecond corresponding DC voltage derived from the portion of the transmitvoltage received by the second input circuit; and

a common power bus (3105) coupled to the second output circuits and tothe heating element;

wherein the second converter circuit is configured to deliver the secondcorresponding DC voltages of the second output circuits to the heatingelement via the common power bus.

299. The thermal storage system of claim 298, wherein each firstconverter circuit further includes a transformer, and wherein the firstinput circuit is further configured to induce, using the time-varying DCvoltage received by the first input circuit, a first current in aprimary coil of the transformer, and wherein the first output circuit isfurther configured to generate the first corresponding DC voltage usinga second current induced in a secondary coil of the transformer.

300. The thermal storage system of claim 299, wherein to generate thefirst corresponding DC voltage, the first output circuit is furtherconfigured to:

rectify the second current to generate an internal supply voltage; and

generate the first corresponding DC voltage using the internal supplyvoltage.

301. The thermal storage system of claim 298, wherein the plurality ofgenerator circuits includes a plurality of photovoltaic cells configuredto generate the plurality of time-varying DC voltages based on anillumination of the photovoltaic cells.

Power transfer system: maintains the voltage across any one of theconverter circuits smaller, allowing for smaller and less expensivecomponents; allows for the creation of a larger transmission voltagewithout using a traditional step-up transformer which could createadditional power transfer losses; and prevents the draw of excessivecurrent from the generator circuits by the power transfer system.

302. A power transfer system, comprising:

a plurality of generator circuits (3103A-C) configured to generate aplurality of time-varying direct current (DC) voltages;

a first converter circuit (3101) that includes a plurality of firstconverter circuits (3203A-C), each first converter circuit including:

a first input circuit (3401) configured to receive one of thetime-varying DC voltages, and a first output circuit (3419) galvanicallyisolated from the input circuit and configured to generate a firstcorresponding DC voltage derived from the time-varying DC voltagereceived by the first input circuit, wherein the first converter circuitis configured to combine the first corresponding DC voltages of thefirst output circuits to generate a transmit voltage and drive atransmission line (3106); and

a second converter circuit (3102) that includes a plurality of secondconverter circuits, each second converter circuit including:

a second input circuit (3401) configured to receive a portion of thetransmit voltage, and a second output circuit (3419) galvanicallyisolated from the second input circuit and configured to generate asecond corresponding DC voltage derived from the portion of the transmitvoltage received by the second input circuit, wherein the secondconverter circuit is configured to deliver the second corresponding DCvoltages of the second output circuits on a common power bus; and

a load (3104) coupled to the common power bus.

303. The power transfer system of claim 302, wherein each firstconverter circuit further includes a transformer, and wherein the firstinput circuit is further configured to induce, using the time-varying DCvoltage received by the first input circuit, a first current in aprimary coil of the transformer, and wherein the first output circuit isfurther configured to generate the first corresponding DC voltage usinga second current induced in a secondary coil of the transformer.

304. The power transfer system of claim 303, wherein to generate thefirst corresponding DC voltage, the first output circuit is furtherconfigured to:

rectify the second current to generate an internal supply voltage; and

generate the first corresponding DC voltage using the internal supplyvoltage.

305. The power transfer system of claim 302, wherein the load includes aheating element configured to receive the second corresponding DCvoltages via the common power bus to heat a thermal storage medium.

306. The power transfer system of claim 305, wherein the load includesan electric vehicle charger configured to charge at least one batteryusing the second corresponding DC voltages.

Apparatus allows for the creation of a larger transmission voltagewithout using a traditional step-up transformer which could createadditional power transfer losses, and prevents the draw of excessivecurrent from the generator circuits by the power transfer system.

307. An apparatus, comprising:

-   -   a first plurality of converter circuits (3203A-C), each        converter circuit including:        -   an input circuit (3401) configured to receive a direct            current (DC) input voltage from a renewable energy source;            and        -   an output circuit (3419) galvanically isolated from the            input circuit and configured to generate a DC output voltage            derived from the DC input voltage;

wherein the output circuits of the first plurality of converter circuitsare coupled in series to combine respective DC output voltages toproduce a transmit voltage; and

a thermal storage unit (3104) including a heating element (3112)configured to receive the transmit voltage to heat a thermal storagemedium (3111).

308. The apparatus of claim 307, wherein each converter circuit furtherincludes a transformer, and wherein the input circuit is furtherconfigured to induce, using the DC input voltage, a first current in aprimary coil of the transformer, and wherein the output circuit isfurther configured to generate the DC output voltage using a secondcurrent induced in a secondary coil of the transformer.

309. The apparatus of claim 308, wherein to generate the DC outputvoltage using the second current, the output circuit is furtherconfigured to:

rectify the second current to generate an internal supply voltage; and

generate the DC output voltage using the internal supply voltage.

310. The apparatus of claim 307, wherein the renewable energy sourceincludes a plurality of photovoltaic cells configured to generate the DCinput voltage based on an illumination of the photovoltaic cells.

Method allows for the creation of a larger transmission voltage withoutusing a traditional step-up transformer which could create additionalpower transfer losses, and prevents the draw of excessive current fromthe generator circuits by the power transfer system.

311. A method, comprising:

receiving, by an input circuit (3401) of a given converter circuit of aplurality of converter circuits (3203A-C), a direct current (DC) inputvoltage from a renewable energy source (3202A-C); C);

generating, by an output circuit (3419) of the given circuit that isgalvanically isolated from the input circuit, a DC output voltagederived from the DC input voltage;

combining respective DC output voltages by coupling the output circuitsof the first plurality of converter circuits in series to produce atransmit voltage (3108); and

heating a thermal storage medium (3104) by a heating element (3112)using the transmit voltage.

312. The method of claim 311, further comprising adding the secondplurality of DC voltages to generate the transmit voltage.

313. The method of claim 311, wherein generating the DC output voltageincludes:

inducing, by the input circuit using the DC input voltage, a firstcurrent in a primary coil of a transformer included in the givenconverter circuit; and

generating, by the output circuit using a second current in a secondarycoil of the transformer, the DC output voltage, wherein the secondcurrent in the secondary coil is based on the first current in theprimary coil of the transformer.

314. The method of claim 313, further comprising:

rectifying, by the output circuit, the second current to generate aninternal supply voltage; and

generating, by the output circuit, the DC output voltage using theinternal supply voltage.

Apparatus: maintains the voltage across any one of the convertercircuits smaller, allowing for smaller and less expensive components;allows for the creation of a larger transmission voltage without using atraditional step-up transformer which could create additional powertransfer losses; and prevents the draw of excessive current from thegenerator circuits by the power transfer system.

315. An apparatus, comprising:

a plurality of first converter circuits (3203A-C), each first convertercircuit including:

a first input circuit (3401) configured to receive a direct current (DC)input voltage from a renewable energy source; and

a first output circuit (3419) galvanically isolated from the first inputcircuit and configured to generate a DC output voltage derived from theDC input voltage, wherein the output circuits of the first plurality ofconverter circuits are coupled in series to combine respective DC outputvoltages to produce a transmit voltage;

a plurality of second converter circuits (3302A-C) coupled in seriesacross the transmit voltage to generate a plurality of voltage portions,wherein each second converter circuit includes:

a second input circuit (3401) configured to receive a correspondingportion of the plurality of voltage portions; and

a second output circuit (3419) galvanically isolated from the secondinput circuit and configured to generate, using the correspondingportion, a DC load voltage; and

a thermal storage unit (3104) configured to heat a thermal storagemedium (3111) using respective DC load voltages from the secondplurality of converter circuits.

316. The apparatus of claim 315, wherein each first converter circuitfurther includes a transformer, and wherein the first input circuit isfurther configured to induce, using the DC input voltage, a firstcurrent in a primary coil of the transformer, and wherein the firstoutput circuit is further configured to generate the DC output voltageusing a second current induced in a secondary coil of the transformer.

317. The apparatus of claim 316, wherein to generate the DC outputvoltage, the first output circuit is further configured to:

rectify the second current to generate an internal supply voltage; and

generate the DC output voltage using the internal supply voltage.

318. The apparatus of claim 315, wherein the renewable energy sourceincludes a plurality of photovoltaic cells configured to generate the DCinput voltage based on an illumination of the photovoltaic cells.

Apparatus allows for the creation of a larger transmission voltagewithout using a traditional step-up transformer which could createadditional power transfer losses, and prevents the draw of excessivecurrent from the generator circuits by the power transfer system.

319. An apparatus, comprising:

-   -   a first plurality of converter circuits (3202A-C), each        converter circuit including:        -   a first input circuit (3401) configured to receive a direct            current (DC) input voltage from a DC voltage source; and        -   a first output circuit (3419) galvanically isolated from the            first input circuit and configured to generate a DC output            voltage based on the DC input voltage; and    -   wherein the first plurality of converter circuits are coupled in        series such that the DC output voltages are combined to produce        a transmit voltage (3108).

320. The apparatus of claim 319, further comprising a load unitincluding an electric vehicle charger configured to charge at least onebattery using the transmit voltage.

321. The apparatus of claim 320, further comprising:

a second plurality of converter circuits (3302A-C) coupled in seriesacross the transmit voltage, wherein each of the second plurality ofconverter circuits includes:

a second input circuit (3401) configured to receive a correspondingportion the transmit voltage; and

a second output circuit (3419) galvanically isolated from the secondinput circuit and configured to generate, using the correspondingportion of the transmit voltage, a DC load voltage; and

a load unit (3306A-B) including an electric vehicle charger configuredto charge at least one battery (3208) using at least one of theplurality of DC load voltages.

Calcination Systems and Methods

Calcium carbonate calcination.

322. A calcination system, comprising:

-   -   a thermal energy storage (TES) system configured to store        thermal energy derived from a renewable energy source, wherein        the TES system includes:        -   a heating element configured to heat a storage medium using            electricity from the renewable energy source; and        -   a blower configured to heat a non-combustive fluid including            carbon dioxide by circulating the non-combustive fluid            through the heated storage medium;    -   the calcination system further comprising a calciner configured        to release carbon dioxide from a supply of calcium carbonate        within the calciner, by:        -   receiving thermal energy obtained from the heated            non-combustive fluid; and        -   applying the received thermal energy to the calcium            carbonate.

323. The calcination system of claim 322, wherein the calciner isconfigured to apply the received thermal energy by:

-   -   injecting calcium carbonate via a first inlet of the calciner;        and    -   injecting, via a second inlet underneath the first inlet, the        heated non-combustive fluid in an up-flow configuration that        suspends the injected calcium carbonate within the calciner.

324. The calcination system of claim 322, further comprising:

-   -   a heat exchanger configured to:        -   heat a second fluid by transferring thermal energy from the            heated non-combustive fluid into the second fluid; and    -   wherein the calciner is configured to apply the received thermal        energy by:        -   injecting the heated second fluid into the calciner to heat            the calcium carbonate.

325. The calcination system of claim 322, further comprising:

-   -   a recirculation system configured to:        -   recover, from the calciner, carbon dioxide produced by the            calcination process; and        -   recirculate the recovered carbon dioxide to the TES system            for inclusion in the non-combustive fluid.

326. The calcination system of claim 322, further comprising:

-   -   a pre-heater configured to:        -   receive additional thermal energy obtain from the heated            non-combustive fluid;        -   apply the additional thermal energy to heat calcium            carbonate to a first temperature; and        -   provide the heated calcium carbonate to the calciner for            heating to a second temperature that is higher than the            first temperature.

Material activation system.

327. A material activation system, comprising:

-   -   a thermal energy storage (TES) system configured to store        thermal energy derived from an energy source, by:        -   heating a storage medium using energy from the renewable            energy source; and        -   circulating a non-combustive fluid through the heated            storage medium; and    -   a material heating system configured to:        -   receive thermal energy derived from the circulated            non-combustive fluid; and        -   apply the received thermal energy to a raw material to            produce an activated material.

328. The material activation system of claim 327, wherein the materialheating system is configured to:

-   -   receive the circulated non-combustive fluid at a first inlet in        the material heating system;    -   inject the raw material via a second inlet positioned above the        first inlet in the material heating system; and    -   direct the fluid in an up-flow configuration such that the raw        material is suspended in the material heating system.

329. The material activation system of claim 327, further comprising:

-   -   a heat exchanger configured to:        -   receive the circulated non-combustive fluid from the TES            system;        -   transfer heat from the circulated non-combustive fluid into            a second fluid; and        -   provide the heated second fluid to the material heating            system for applying the thermal energy to the raw material.

330. The material activation system of claim 329, further comprising:

-   -   a bypass configured to inject a portion of the circulated        non-combustive fluid received from the TES system into the        second fluid provided to the material heating system.

331. The material activation system of claim 327, further comprising:

-   -   a pre-heater configured to:        -   apply thermal energy derived from the circulated            non-combustive fluid to heat the raw material to a first            temperature; and        -   provide the heated raw material as an input to the material            heating system for heating to a second temperature.

332. The material activation system of claim 327, further comprising:

-   -   a recirculation system configured to:        -   recirculate an exhaust fluid output from the material            heating system to the TES system as an input.

333. The material activation system of claim 332, further comprising:

-   -   a cooling cyclone configured to:        -   receive the activated material from the material heating            system; and        -   reduce a temperature of the activated material; and    -   wherein the recirculation system is configured to:        -   collect, from the cooling cyclone, the exhaust fluid for            recirculation.

334. The material activation system of claim 333, wherein therecirculation system includes:

-   -   a filter coupled between the material heating system and the TES        system, wherein the filter is configured to remove particulate        from the exhaust fluid prior to the exhaust fluid being provided        to the TES system.

335. The material activation system of claim 327, wherein the materialheating system is configured to perform a calcination process thattransforms calcium carbonate as the raw material into calcium oxide asthe activated material for cement production.

336. The material activation system of claim 335, further comprising arecirculation system configured to recirculate carbon dioxide producedby the calcination process to the TES system for use as thenon-combustive fluid.

337. The material activation system of claim 327, wherein the materialheating system is configured to perform a dehydroxylation process thatremoves hydroxide from clay minerals as the raw material to produceactivated clay as the activated material.

338. The material activation system of claim 337, further comprising:

-   -   an atmosphere reduction system coupled to the material heating        system and configured to reduce an amount of oxygen in contact        with the activated clay.

339. The material activation system of claim 327, wherein the materialheating system is configured to implement a Bayer process thattransforms bauxite as the raw material to produce aluminum oxide as theactivated material.

340. The material activation system of claim 339, wherein the materialheating system is configured to:

-   -   Implement a first stage of the Bayer process that includes        heating the bauxite to a temperature within a range from 300° C.        to 480° C. and at a first pressure within a range of 6 bar to 8        bar;    -   implement a second stage of the Bayer process that includes        elevating a temperature of the bauxite within a temperature        range from 750° C. to 950° C. and a second pressure lower than        the first pressure; and    -   recirculate, from the second stage to the first stage, the        thermal energy derived from the circulated non-combustive fluid.

341. The material activation system of claim 327, further comprising:

-   -   a burner configured to supply combustion energy to the material        heating system in addition to the thermal energy supplied by the        TES system.

342. The material activation system of claim 327, further comprising:

-   -   a steam cycle system that includes:        -   a heat exchanger configured to produce steam from thermal            energy recovered from the material heating system; and        -   a stream turbine configured to generate electricity from the            produced steam.

343. The material activation system of claim 327, wherein the TES systemis configured to:

-   -   provide the circulated non-combustive fluid to the material        heating system at a temperate within a range of from 600° C. to        1100° C.

344. The material activation system of claim 327, wherein thenon-combustive fluid is carbon dioxide.

345. The material activation system of claim 327, wherein the storagemedium includes brick.

346. The material activation system of claim 327, wherein the heatingelement includes one or more ceramic resistive heaters.

Method of material activation.

347. A method for material activation, comprising:

-   -   receiving, by a thermal energy storage (TES) system of a        material activation system, energy supplied by an energy source;    -   storing, by the TES system, the received energy as thermal        energy by heating a storage medium with the received energy;    -   providing, by the TES system to a material heating system of the        material activation system, the stored thermal energy by        circulating a non-combustive fluid through the heated storage        medium; and    -   implementing, by the material heating system, a material        activation process that includes applying the provided thermal        energy to a raw material to produce an activated material.

348. The method of claim 347, further comprising:

-   -   recovering, by the material activation system, thermal energy        from an output of material heating system; and    -   recirculating, to the TES system, a fluid including the        recovered thermal energy.

349. The method of claim 347, wherein the martial activation processproduces calcium oxide and carbon dioxide from calcium carbonate; and

-   -   wherein the method further comprises:        -   recirculating, by the material activation system, the carbon            dioxide to the TES system for use as the non-combustive            fluid.

350. The method of claim 347, wherein the martial activation processproduces activated clay and hydroxide from clay minerals; and

-   -   wherein the method further comprises:        -   reducing, by an atmosphere reduction zone of the material            activation system, an amount of oxygen in contact with the            activated clay.

Material activation system.

351. A material activation system, comprising:

-   -   a non-combustive means for heating a storage medium using energy        from a variable energy source;    -   a means for transferring thermal energy from the storage medium        to a fluid; and    -   a means for applying the transferred thermal energy from the        fluid to a raw material to produce an activated material.

Calcination system.

352. A calcination system, comprising:

-   -   a thermal energy storage (TES) system configured to store        thermal energy derived from an energy source, wherein the TES        system includes:        -   a heating element configured to heat a storage medium using            electricity from the energy source; and        -   a blower configured to heat a non-combustive fluid by            circulating the non-combustive fluid through the heated            storage medium;    -   the calcination system further comprising a calciner configured        to remove carbon dioxide from a supply of calcium carbonate        within the calciner, by:        -   receiving thermal energy obtained from the heated            non-combustive fluid; and        -   applying the received thermal energy to the calcium            carbonate.

System using thermal energy storage discharge for a solid oxideelectrolysis system to efficiently produce hydrogen from electrolysis ofwater.

353. A system, comprising:

a thermal energy storage (TES) system (4801) configured to store thermalenergy derived from a renewable energy source (4903), wherein the TESsystem includes:

a storage medium configured to store thermal energy; and

a heating element configured to heat the storage medium usingelectricity from the renewable energy source; and

a fluid movement system (213, 4223) configured to move a fluid throughthe storage medium to heat the fluid to a temperature in a specifiedtemperature range; and

an electrolysis system (4803), wherein the electrolysis system includes:

a plurality of solid oxide cells (4803) configured to electrolyze waterto produce hydrogen when an electric potential is provided to the solidoxide cells; and

a sweep path across the solid oxide cells, wherein the sweep path isconfigured to circulate the fluid from the fluid movement system totransfer heat to the solid oxide cells.

354. The system of claim 353, wherein the fluid comprises a mixture ofoxygen and nitrogen.

355. The system of claim 353, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

356. The system of claim 353, wherein a volume percentage of hydrogen ina product fluid produced by electrolysis is greater than a volumepercentage of hydrogen in the water provided to the solid oxide cells.

357. The system of claim 353, wherein the water provided to the solidoxide cells comprises water and hydrogen.

358. The system of claim 353, wherein the water comprises at least 90%water.

359. The system of claim 353, wherein the specified temperature range is800° C. to 900° C.

360. The system of claim 353, wherein the water is at a temperaturebelow the temperature of the fluid but above 800° C.

361. The system of claim 353, wherein the fluid has a flow rate of atleast 1500 kg/hr.

362. The system of claim 353, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

363. The system of claim 353, wherein hydrogen produced by electrolysisis at a temperature above a temperature of the water.

364. The system of claim 353, wherein the electric potential provided tothe solid oxide cells is between 1 volt and 3 volts.

365. The system of claim 353, wherein the fluid provides an amount ofheat sufficient to maintain electrolysis of water in the solid oxidecells.

366. The system of claim 353, further comprising a steam generator(4805) configured to condense the hydrogen and generate steam byexchanging heat from the hydrogen with water.

367. The system of claim 353, wherein at least some of the steamgenerated by the steam generator (4805) is configured to be recirculatedto the solid oxide cells.

368. The system of claim 367, wherein the recirculated fluid includes atleast some hydrogen gas.

369. The system of claim 368, wherein at least some of the condensedhydrogen is configured to be stored.

370. The system of claim 353, wherein the fluid is enriched with atleast some of oxygen produced by the electrolysis of water in the solidoxide cells.

371. The system of claim 370, wherein the oxygen enriched fluid has avolume percentage of oxygen above the volume percentage of oxygen in thefluid.

372. The system of claim 370, wherein a temperature of the hydrogen isnear a temperature of the oxygen enriched fluid.

373. The system of claim 370, wherein the oxygen enriched fluid includesoxygen and nitrogen.

374. The system of claim 370, wherein a temperature of the oxygenenriched fluid is between a temperature of the water and a temperatureof the fluid.

375. The system of claim 370, wherein the oxygen enriched fluid isprovided to the thermal energy storage system.

376. The system of claim 370, further comprising a steam generator(4807) configured to generate steam by exchanging heat from the oxygenenriched fluid with water.

377. The system of claim 353, wherein the water comprises water andcarbon dioxide.

378. The system of claim 377, wherein the water and carbon dioxide isconfigured to be converted to carbon monoxide and hydrogen byelectrolysis in the solid oxide cells.

379. The system of claim 378, further comprising a syngas conversionsystem (4109) configured to produce a synthetic hydrocarbon fluid fromthe produced hydrogen and carbon monoxide.

Method using thermal energy storage discharge for a solid oxideelectrolysis system to efficiently produce hydrogen from electrolysis ofwater.

380. A method, comprising:

heating a storage medium using heating elements that convert electricityfrom a renewable energy source (4903) to heat;

circulating a fluid through the storage medium to heat the fluid to atemperature in a specified temperature range;

circulating the fluid across a plurality of solid oxide cells (4803);

providing water to the solid oxide cells (4803); and

providing an electric potential to the solid oxide cells (4803) toelectrolyze the water and generate hydrogen.

381. The method of claim 380, wherein the fluid comprises a mixture ofoxygen and nitrogen.

382. The method of claim 380, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

383. The method of claim 380, wherein a volume percentage of hydrogen ina product fluid produced by electrolysis is greater than a volumepercentage of hydrogen in the water provided to the solid oxide cells.

384. The method of claim 380, wherein the water provided to the solidoxide cells comprises water and hydrogen.

385. The method of claim 380, wherein the water comprises at least 90%water.

386. The method of claim 380, wherein the specified temperature range is800° C. to 900° C.

387. The method of claim 380, wherein the water is at a temperaturebelow the temperature of the fluid but above 800° C.

388. The method of claim 380, wherein the fluid has a flow rate of atleast 1500 kg/hr.

389. The method of claim 380, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

390. The method of claim 380, wherein hydrogen produced by electrolysisis at a temperature above a temperature of the water.

391. The method of claim 380, wherein the electric potential provided tothe solid oxide cells is between 1 volt and 3 volts.

392. The method of claim 380, wherein the fluid provides an amount ofheat sufficient to maintain electrolysis of water in the solid oxidecells.

393. The method of claim 380, further comprising providing the hydrogento a steam generator (4805) to condense the hydrogen and generate steamby exchanging heat from the hydrogen with water.

394. The method of claim 393, further comprising adding a recirculatedfluid to the water provided to the solid oxide cells, wherein therecirculated fluid includes at least some of the steam generated by thesteam generator.

395. The method of claim 394, wherein the recirculated fluid includes atleast some hydrogen gas.

396. The method of claim 393, further comprising storing at least someof the condensed hydrogen.

397. The method of claim 380, wherein the electrolysis of water producesoxygen, and wherein the fluid is enriched with at least some of theproduced oxygen.

398. The method of claim 397, wherein a temperature of the hydrogen isnear a temperature of the oxygen enriched fluid.

399. The method of claim 397, wherein the oxygen enriched fluid has avolume percentage of oxygen above the volume percentage of oxygen in thefluid.

400. The method of claim 397, wherein the oxygen enriched fluid includesoxygen and nitrogen.

401. The method of claim 397, wherein a temperature of the oxygenenriched fluid is between a temperature of the water and a temperatureof the fluid.

402. The method of claim 397, further comprising providing the oxygenenriched fluid to the thermal energy storage system, and:

implementing the oxygen enriched fluid in continued operation of thethermal energy storage system; or

implementing the oxygen enriched fluid in the conversion of the inputelectricity to stored thermal energy.

403. The method of claim 397, further comprising providing the oxygenenriched fluid to a steam generator (4807) to generate steam byexchanging heat from the oxygen enriched fluid with water.

404. The method of claim 380, wherein the water provided to the solidoxide cells comprises water and carbon dioxide.

405. The method of claim 404, wherein the water and carbon dioxide isconverted to carbon monoxide and hydrogen by electrolysis in the solidoxide cells.

406. The method of claim 405, further comprising providing the hydrogenand carbon monoxide to a syngas conversion system (4109) to produce asynthetic hydrocarbon fluid.

System using stored thermal energy in a fuel cell system to converthydrogen to electricity and water.

407. A system, comprising:

a thermal energy storage (TES) system (5001) configured to store thermalenergy derived from a renewable energy source (4903), wherein the TESsystem includes:

a storage medium configured to store thermal energy; and

a heating element configured to heat the storage medium usingelectricity from the renewable energy source; and

a fluid movement system (213, 4223) configured to move a fluid throughthe storage medium to heat the fluid to a temperature in a specifiedtemperature range; and

a fuel cell system (5007), wherein the fuel cell system includes:

a plurality of solid oxide cells (5007) configured to generateelectricity and water when hydrogen is provided to the solid oxidecells; and

a sweep path across the solid oxide cells (5007), wherein the sweep pathis configured to circulate the fluid from the fluid movement system toremove heat from the solid oxide cells.

408. The system of claim 407, wherein the fluid comprises a mixture ofoxygen and nitrogen.

409. The system of claim 407, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

410. The system of claim 407, wherein the specified temperature range is600° C. and 700° C.

411. The system of claim 407, wherein the fluid has a flow rate of atleast 1500 kg/hr.

412. The system of claim 407, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

413. The system of claim 407, further comprising a heat exchanger (5013)configured to heat hydrogen fed to the solid oxide cells with the fluid.

414. The system of claim 407, wherein the hydrogen provided to the solidoxide cells includes at least some steam.

415. The system of claim 407, wherein the fluid is configured tomaintain a temperature of the solid oxide cells.

416. The system of claim 407, wherein the electricity generated isdirect current electricity.

417. The system of claim 407, wherein at least a portion of the residualhydrogen from the solid oxide cells is configured to be recirculated tothe solid oxide cells.

418. The system of claim 407, wherein at least a portion of the fluidthat sweeps through the solid oxide cells is provided to the TES system.

Method using stored thermal energy in a fuel cell system to converthydrogen to electricity and water.

419. A method, comprising:

heating a storage medium using heating elements that convert electricityfrom a renewable energy source (4903) to heat;

circulating a fluid through the storage medium to heat the fluid to atemperature in a specified temperature range;

circulating the fluid across a plurality of solid oxide cells (5007);

providing hydrogen to the solid oxide cells (5007); and

generating electricity and water from the solid oxide cells (5007).

420. The method of claim 419, wherein the fluid comprises a mixture ofoxygen and nitrogen.

421. The method of claim 419, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

422. The method of claim 419, wherein the specified temperature range is600° C. and 700° C.

423. The method of claim 419, wherein the fluid has a flow rate of atleast 1500 kg/hr.

424. The method of claim 419, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

425. The method of claim 419, further comprising heating hydrogen fed tothe solid oxide cells with the fluid in a heat exchanger (5013).

426. The method of claim 419, further comprising adding steam to thehydrogen provided to the solid oxide cells.

427. The method of claim 419, wherein the fluid removes heat from thesolid oxide cells.

428. The method of claim 419, wherein the electricity generated isdirect current electricity.

429. The method of claim 419, further comprising recirculating at leasta portion of the residual hydrogen produced from the solid oxide cellsto the solid oxide cells.

430. The method of claim 419, further comprising providing at least aportion of the fluid that sweeps through the solid oxide cells to thestorage medium.

System in which solid oxide cells are reversible to be used for eitherelectrolysis or fuel cell operations, allowing fluid to be constantlyprovided to the cells to maintain the cells at elevated temperatureswhile switching between modes of operation.

431. A system, comprising:

a thermal energy storage (TES) system (4801) configured to store thermalenergy derived from a renewable energy source (4903), wherein the TESsystem includes:

a storage medium configured to store thermal energy; and

a heating element configured to heat the storage medium usingelectricity from the renewable energy source; and

a fluid movement system (213, 4223) configured to move a fluid throughthe storage medium to heat the fluid to a temperature in a specifiedtemperature range; and

a plurality of solid oxide cells (4803), wherein the solid oxide cellsare configured to:

electrolyze water to produce hydrogen when an electric potential isprovided to the solid oxide cells;

generate electricity and water when hydrogen is provided to the solidoxide cells; and

a sweep path across the solid oxide cells, wherein the sweep path isconfigured to circulate the fluid from the fluid movement system totransfer heat between the fluid and the solid oxide cells.

432. The system of claim 431, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

433. The system of claim 431, wherein a volume percentage of hydrogen ina product fluid produced by electrolysis is greater than a volumepercentage of hydrogen in the water provided to the solid oxide cells.

434. The system of claim 431, wherein the water provided to the solidoxide cells comprises water and hydrogen.

435. The system of claim 431, wherein the water for electrolysiscomprises at least 90% water.

436. The system of claim 431, wherein the specified temperature range is800° C. to 900° C.

437. The system of claim 431, wherein the specified temperature range is600° C. and 700° C.

438. The system of claim 431, wherein the water for electrolysisreaction is at a temperature below the temperature of the fluid butabove 800° C.

439. The system of claim 431, wherein the fluid has a flow rate of atleast 1500 kg/hr.

440. The system of claim 431, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

441. The system of claim 431, wherein hydrogen produced by electrolysisis at a temperature above a temperature of the water for electrolysis.

442. The system of claim 431, wherein the electric potential provided tothe solid oxide cells for electrolysis is between 1 volt and 3 volts.

443. The system of claim 431, wherein the fluid provides an amount ofheat sufficient to maintain electrolysis of water in the solid oxidecells.

444. The system of claim 431, wherein the electrolysis of water producesoxygen, and wherein the fluid is enriched with at least some of theproduced oxygen.

445. The system of claim 444, wherein the oxygen enriched fluid has avolume percentage of oxygen above the volume percentage of oxygen in thefluid.

446. The system of claim 444, wherein a temperature of the hydrogenproduced by electrolysis is near a temperature of the oxygen enrichedfluid produced by electrolysis.

447. The system of claim 444, wherein the oxygen enriched fluid includesoxygen and nitrogen.

448. The system of claim 444, wherein a temperature of the oxygenenriched fluid is between a temperature of the water for electrolysisand a temperature of the fluid.

449. The system of claim 444, wherein the oxygen enriched fluid isconfigured to be provided to the thermal energy storage system, andwherein the thermal energy storage system is configured to:

implement the oxygen enriched fluid in continued operation of thethermal energy storage system; or

implement the oxygen enriched fluid in the conversion of the inputelectricity to stored thermal energy.

System providing heated fluid for electrolysis, the heat being providedfrom a high-efficiency TES system and used to increase efficiency ofelectrolysis reaction.

450. A thermal energy storage (TES) system (4801), comprising:

a storage medium configured to store thermal energy; and

a heating element configured to heat the storage medium usingelectricity from a renewable energy source (4903); and

a fluid movement system (213, 4223) configured to move a fluid throughthe storage medium to heat the fluid to a temperature in a specifiedtemperature range and provide the fluid to a solid oxide electrolysissystem (4803) that converts water to hydrogen.

451. The system of claim 450, wherein the fluid comprises a mixture ofoxygen and nitrogen.

452. The system of claim 450, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

453. The system of claim 450, wherein a volume percentage of hydrogen ina product fluid produced by electrolysis is greater than a volumepercentage of hydrogen in the water provided to the solid oxide cells.

454. The system of claim 450, wherein the specified temperature range is800° C. to 900° C.

455. The system of claim 450, wherein the fluid has a flow rate of atleast 1500 kg/hr.

456. The system of claim 450, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

457. The system of claim 450, wherein the fluid provides an amount ofheat sufficient to maintain electrolysis of water in the solid oxidecells.

Method providing heated fluid for electrolysis, the heat being providedfrom a high-efficiency TES system and used to increase efficiency ofelectrolysis reaction.

458. A method, comprising:

heating a storage medium using heating elements that convert electricityfrom a renewable energy source (4903) into heat;

circulating a fluid through the storage medium to heat the fluid to atemperature in a specified temperature range; and

providing the fluid to a solid oxide electrolysis system (4803) thatconverts water to hydrogen.

459. The method of claim 458, wherein the fluid comprises a mixture ofoxygen and nitrogen.

460. The method of claim 458, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

461. The method of claim 458, wherein the specified temperature range is800° C. to 900° C.

462. The method of claim 458, wherein the fluid has a flow rate of atleast 1500 kg/hr.

463. The method of claim 458, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

464. The method of claim 458, wherein the fluid provides an amount ofheat sufficient to maintain electrolysis of water in the solid oxidecells.

465. The method of claim 458, further comprising receiving at least someoxygen enriched fluid from solid oxide cells in the thermal energystorage system, the method further comprising:

implementing the oxygen enriched fluid in continued operation of thethermal energy storage system; or

implementing the oxygen enriched fluid in the conversion of the inputelectricity to stored thermal energy.

System providing heated fluid for electrolysis, the heat being providedfrom a high-efficiency TES system and used to increase efficiency ofelectrolysis reaction.

466. A thermal energy storage (TES) system (5001), comprising:

a storage medium configured to store thermal energy;

a heating element configured to heat the storage medium usingelectricity from a renewable energy source (4903); and

a fluid movement system (213, 4223) configured to move a fluid throughthe storage medium to heat the fluid to a temperature in a specifiedtemperature range and provide the fluid to a solid oxide fuel cellsystem (5007) that generates electricity and water from hydrogen.

467. The system of claim 466, wherein the fluid comprises a mixture ofoxygen and nitrogen.

468. The system of claim 466, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

469. The system of claim 466, wherein the specified temperature range is600° C. and 700° C.

470. The system of claim 466, wherein the fluid has a flow rate of atleast 1500 kg/hr.

471. The system of claim 466, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

472. The system of claim 466, wherein the fluid is configured tomaintain a temperature of the solid oxide cells.

473. The system of claim 466, wherein at least a portion of the fluidthat sweeps through the solid oxide cells is recirculated to the storagemedium.

Method using stored thermal energy in a fuel cell system to converthydrogen to electricity and water.

474. A method, comprising:

heating a storage medium using heating elements that convert electricityfrom a renewable energy source (4903) into heat;

circulating a fluid through the storage medium to heat the fluid to atemperature in a specified temperature range; and

providing the fluid to a solid oxide fuel cell system (5007) thatgenerates electricity and water from hydrogen.

475. The method of claim 474, wherein the fluid comprises a mixture ofoxygen and nitrogen.

476. The method of claim 474, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

477. The method of claim 474, wherein the specified temperature range is600° C. and 700° C.

478. The method of claim 474, wherein the fluid has a flow rate of atleast 1500 kg/hr.

479. The method of claim 474, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

480. The method of claim 474, wherein the fluid removes heat from thesolid oxide cells.

481. The method of claim 474, further comprising providing at least aportion of the fluid that sweeps through the solid oxide cells to thestorage medium.

Electrolysis system providing heated fluid for electrolysis, the heatbeing provided from a high-efficiency TES system and used to increaseefficiency of electrolysis reaction.

482. An electrolysis system, comprising:

a plurality of solid oxide cells (4803) configured to electrolyze waterto produce hydrogen when an electric potential is provided to the solidoxide cells; and

a sweep path across the solid oxide cells (4803), wherein the sweep pathis configured to circulate a fluid received from a thermal energystorage system (4801), wherein the fluid is heated by circulating thefluid through a storage medium storing thermal energy generated byconversion of input electricity from a renewable energy source, andwherein the fluid is heated to a temperature in a specified temperaturerange.

483. The system of claim 482, wherein the fluid comprises a mixture ofoxygen and nitrogen.

484. The system of claim 482, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

485. The system of claim 482, wherein a volume percentage of hydrogen ina product fluid produced by electrolysis is greater than a volumepercentage of hydrogen in the water provided to the solid oxide cells.

486. The system of claim 482, wherein the water provided to the solidoxide cells comprises water and hydrogen.

487. The system of claim 482, wherein the water comprises at least 90%water.

488. The system of claim 482, wherein the specified temperature range is800° C. to 900° C.

489. The system of claim 482, wherein the water is at a temperaturebelow the temperature of the fluid but above 800° C.

490. The system of claim 482, wherein the fluid has a flow rate of atleast 1500 kg/hr.

491. The system of claim 482, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

492. The system of claim 482, wherein hydrogen produced by electrolysisis at a temperature above a temperature of the water.

493. The system of claim 482, wherein the electric potential provided tothe solid oxide cells is between 1 volt and 3 volts.

494. The system of claim 482, wherein the fluid provides an amount ofheat sufficient to maintain electrolysis of water in the solid oxidecells.

495. The system of claim 482, further comprising a steam generator(4805) configured to condense the hydrogen and generate steam byexchanging heat from the hydrogen with water.

496. The system of claim 495, wherein at least some of the steamgenerated by the steam generator is configured to be recirculated to thesolid oxide cells.

497. The system of claim 496, wherein the recirculated fluid includes atleast some hydrogen gas.

498. The system of claim 495, wherein at least some of the condensedhydrogen is configured to be stored.

499. The system of claim 482, wherein the fluid is enriched with atleast some of oxygen produced by the electrolysis of water in the solidoxide cells.

500. The system of claim 499, wherein the oxygen enriched fluid has avolume percentage of oxygen above the volume percentage of oxygen in thefluid.

501. The system of claim 499, wherein a temperature of the hydrogen isnear a temperature of the oxygen enriched fluid.

502. The system of claim 499, wherein the oxygen enriched fluid includesoxygen and nitrogen.

503. The system of claim 499, wherein a temperature of the oxygenenriched fluid is between a temperature of the water and a temperatureof the fluid.

504. The system of claim 499, wherein the oxygen enriched fluid isprovided to the thermal energy storage system (4801).

505. The system of claim 499, further comprising a steam generator(4807) configured to generate steam by exchanging heat from the oxygenenriched fluid with water.

506. The system of claim 482, wherein the water comprises water andcarbon dioxide.

507. The system of claim 506, wherein the water and carbon dioxide areconfigured to be converted to carbon monoxide and hydrogen byelectrolysis in the solid oxide cells.

508. The system of claim 506, further comprising a syngas conversionsystem (4109) configured to produce a synthetic hydrocarbon fluid fromthe produced hydrogen and carbon monoxide.

Electrolysis method providing heated fluid for electrolysis, the heatbeing provided from a high-efficiency TES system and used to increaseefficiency of electrolysis reaction.

509. A method of electrolysis, comprising:

circulating a fluid across a plurality of solid oxide cells (4803),wherein the fluid has been heated by a storage medium storing thermalenergy generated by conversion of input electricity from a renewableenergy source (4903);

providing water to the solid oxide cells (4803); and

providing an electric potential to the solid oxide cells (4803) toelectrolyze the water and generate hydrogen.

510. The method of claim 509, wherein the fluid comprises a mixture ofoxygen and nitrogen.

511. The method of claim 509, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

512. The method of claim 509, wherein a volume percentage of hydrogen ina product fluid produced by electrolysis is greater than a volumepercentage of hydrogen in the water provided to the solid oxide cells.

513. The method of claim 509, wherein the water provided to the solidoxide cells comprises water and hydrogen.

514. The method of claim 509, wherein the water comprises at least 90%water.

515. The method of claim 509, wherein the specified temperature range is800° C. to 900° C.

516. The method of claim 509, wherein the water is at a temperaturebelow the temperature of the fluid but above 800° C.

517. The method of claim 509, wherein the fluid has a flow rate of atleast 1500 kg/hr.

518. The method of claim 509, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

519. The method of claim 509, wherein hydrogen produced by electrolysisis at a temperature above a temperature of the water.

520. The method of claim 509, wherein the electric potential provided tothe solid oxide cells is between 1 volt and 3 volts.

521. The method of claim 509, wherein the fluid provides an amount ofheat sufficient to maintain electrolysis of water in the solid oxidecells.

522. The method of claim 509, further comprising providing the hydrogento a steam generator (4805) to condense the hydrogen and generate steamby exchanging heat from the hydrogen with water.

523. The method of claim 522, further comprising adding a recirculatedfluid to the water provided to the solid oxide cells, wherein therecirculated fluid includes at least some of the steam generated by thesteam generator.

524. The method of claim 523, wherein the recirculated fluid includes atleast some hydrogen gas.

525. The method of claim 522, further comprising storing at least someof the condensed hydrogen.

526. The method of claim 509, wherein the electrolysis of water producesoxygen, and wherein the fluid is enriched with at least some of theproduced oxygen.

527. The method of claim 526, wherein the oxygen enriched fluid has avolume percentage of oxygen above the volume percentage of oxygen in thefluid.

528. The method of claim 526, wherein a temperature of the hydrogen isnear a temperature of the oxygen enriched fluid.

529. The method of claim 526, wherein the oxygen enriched fluid includesoxygen and nitrogen.

530. The method of claim 526, wherein a temperature of the oxygenenriched fluid is between a temperature of the water and a temperatureof the fluid.

531. The method of claim 526, further comprising providing the oxygenenriched fluid to a thermal energy storage system (4801), and:

implementing the oxygen enriched fluid in continued operation of thethermal energy storage system; or

implementing the oxygen enriched fluid in the conversion of the inputelectricity to stored thermal energy.

532. The method of claim 526, further comprising providing the oxygenenriched fluid to a steam generator (4807) to generate steam byexchanging heat from the oxygen enriched fluid with water.

533. The method of claim 509, wherein the water provided to the solidoxide cells comprises water and carbon dioxide.

534. The method of claim 533, wherein the water and carbon dioxide areconverted to carbon monoxide and hydrogen by electrolysis in the solidoxide cells.

535. The method of claim 534, further comprising providing the hydrogenand carbon monoxide to a syngas conversion system (4109) to produce asynthetic hydrocarbon fluid.

System providing heated fluid for electrolysis, the heat being providedfrom a high-efficiency TES system and used to increase efficiency ofelectrolysis reaction.

536. A fuel cell system comprising:

a plurality of solid oxide cells (5007) configured to generateelectricity and hydrogen from water; and

a sweep path across the solid oxide cells (5007), wherein the sweep pathis configured to circulate a fluid received from a thermal energystorage system (5001), wherein the fluid is heated by circulating thefluid through a storage medium storing thermal energy generated byconversion of input electricity from a renewable energy source (4903),and wherein the fluid is heated to a temperature in a specifiedtemperature range.

537. The system of claim 536, wherein the fluid comprises a mixture ofoxygen and nitrogen.

538. The system of claim 536, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

539. The system of claim 536, wherein the specified temperature range is600° C. and 700° C.

540. The system of claim 536, wherein the fluid has a flow rate of atleast 1500 kg/hr.

541. The system of claim 536, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

542. The system of claim 536, further comprising a heat exchanger (5013)configured to heat hydrogen fed to the solid oxide cells with the fluid.

543. The system of claim 536, wherein the hydrogen provided to the solidoxide cells includes at least some steam.

544. The system of claim 536, wherein the fluid is configured tomaintain a temperature of the solid oxide cells.

545. The system of claim 536, wherein the electricity generated isdirect current electricity.

546. The system of claim 536, wherein at least a portion of the residualhydrogen from the solid oxide cells is configured to be recirculated tothe solid oxide cells.

547. The system of claim 536, wherein at least a portion of the fluidthat sweeps through the solid oxide cells is provided to the storagemedium.

Method providing heated fluid for electrolysis, the heat being providedfrom a high-efficiency TES system and used to increase efficiency ofelectrolysis reaction.

548. A method, comprising:

circulating a fluid across a plurality of solid oxide cells (5007),wherein the fluid has been heated by a storage medium storing thermalenergy generated by conversion of input electricity from a renewableenergy source (4903);

providing hydrogen to the solid oxide cells (5007); and

generating electricity and water from the solid oxide cells (5007).

549. The method of claim 548, wherein the fluid comprises a mixture ofoxygen and nitrogen.

550. The method of claim 548, wherein the fluid has a volume percentageof oxygen that is above 25% and below 60%.

551. The method of claim 548, wherein the specified temperature range is600° C. and 700° C.

552. The method of claim 548, wherein the fluid has a flow rate of atleast 1500 kg/hr.

553. The method of claim 548, wherein the fluid has a flow rate between1500 kg/hr and 2000 kg/hr.

554. The method of claim 548, further comprising heating hydrogen fed tothe solid oxide cells with the fluid in a heat exchanger (5013).

555. The method of claim 548, further comprising adding steam to thehydrogen provided to the solid oxide cells.

556. The method of claim 548, wherein the fluid removes heat from thesolid oxide cells.

557. The method of claim 548, wherein the electricity generated isdirect current electricity.

558. The method of claim 548, further comprising recirculating at leasta portion of the residual hydrogen produced from the solid oxide cellsto the solid oxide cells.

559. The method of claim 548, further comprising providing at least aportion of the fluid that sweeps through the solid oxide cells to thestorage medium.

Apparatus for cogeneration using heat from solid oxide electrolyzes togenerate steam and reducing waste of energy.

560. An apparatus comprising:

a thermal storage assemblage (4100) including a plurality of thermalstorage blocks, wherein at least some of the thermal storage blocksinclude multiple fluid flow slots, wherein at least some of the fluidflow slots are configured to define fluid pathways through the thermalstorage blocks;

a plurality of heater elements (3607) positioned within the thermalstorage assemblage, wherein each of the plurality of heater elements isconfigured to heat at least one of the thermal storage blocks;

a fluid movement system (213, 4223) configured to direct a stream offluid through the fluid pathways to heat the fluid to a specifiedtemperature range, wherein the fluid movement device is configured toprovide the heated fluid in the specified temperature range to a solidoxide electrolysis system configured to extract hydrogen from water andoutput the heated fluid at a lower temperature; and

a steam generator configured to receive the lower-temperature fluid fromthe electrolysis system convert input feed water into steam.

561. The apparatus of claim 560, wherein the steam generator is aonce-through steam generator.

562. The apparatus of claim 560, wherein the steam generator is a heatrecovery steam generator.

563. The apparatus of claim 560, wherein the steam generator includes aplurality of conduits coupled to receive the input feed water, whereinselected ones of the conduits are arranged to mitigate scale formationand overheating.

564. The apparatus of claim 563, wherein ones of the plurality ofconduits are arranged in the steam generator transversely to a path offlow of the lower temperature fluid.

565. The apparatus of claim 560, wherein the thermal storage assemblycomprises:

-   -   an enclosure containing the plurality of thermal storage blocks;        and

a thermal barrier separating a first subset of the plurality of thermalstorage blocks from a second subset of the plurality of thermal storageblocks.

566. The apparatus of claim 565, wherein the fluid movement system isconfigured to direct the stream of fluid through the fluid pathways ofone of the first and second subsets of thermal concurrent with anelectricity source adding heat to another one of the first and secondsub set.

567. The apparatus of claim 560, wherein the fluid comprises oxygen andnitrogen.

568. The apparatus of claim 560, wherein the thermal storage assemblageis configured to store thermal energy generated by a conversion of inputelectricity from an first input energy supply, the first input energysupply having intermittent availability.

569. The apparatus of claim 568, wherein the thermal storage assemblageis further configured to store thermal energy generated by a conversionof input electricity from an second input energy supply configured toprovide electricity on demand.

Apparatus for cogeneration to use steam output from a steam turbine inan industrial process, reducing waste of energy.

570. An apparatus comprising:

a thermal storage assemblage (4100) including a plurality of thermalstorage blocks, wherein at least some of the thermal storage blocksinclude multiple fluid flow slots, wherein at least some of the fluidflow slots are configured to define fluid pathways through the thermalstorage blocks;

a plurality of heater elements (3607) positioned within the thermalstorage assemblage, wherein each of the plurality of heater elements isconfigured to heat at least one of the thermal storage blocks;

a fluid movement system (213, 4223) configured to direct a stream offluid through the fluid pathways to heat the fluid to a specifiedtemperature range;

a steam generator configured to receive the fluid to convert input feedwater into input steam having a first pressure;

a steam turbine configured to receive the input steam and provide outputsteam at a second pressure that is less than the first pressure; and

a second fluid movement device configured to move the output steam foruse in an industrial process.

571. The apparatus of claim 570, wherein the steam generator is asuperheat boiler.

572. The apparatus of claim 570, wherein the steam generator includes aplurality of conduits coupled to receive the input feed water, whereinselected ones of the conduits are arranged to mitigate scale formationand overheating.

573. The apparatus of claim 572, wherein ones of the plurality ofconduits are arranged in the steam generator transversely to a path offlow of the lower temperature fluid.

574. The apparatus of claim 570, wherein the industrial processcomprises producing petroleum-based fuels.

575. The apparatus of claim 570, wherein the industrial processcomprises producing biofuels.

576. The apparatus of claim 570, wherein the industrial processcomprises producing diesel fuels.

577. The apparatus of claim 570, wherein the industrial processcomprises drying grains.

578. The apparatus of claim 570, wherein the steam turbine is configuredto cause an electrical generator to provide electricity to theindustrial process.

Apparatus providing heat from thermal storage assemblage to generatesteam for a turbine with turbine waste heat being used to preheat feedwater for a high-pressure once-through steam generator.

579. An apparatus comprising:

a thermal storage assemblage (4100) including a plurality of thermalstorage blocks, wherein at least some of the thermal storage blocksinclude multiple fluid flow slots, wherein at least some of the fluidflow slots are configured to define fluid pathways through the thermalstorage blocks;

a plurality of heater elements (3607) positioned within the thermalstorage assemblage, wherein each of the plurality of heater elements isconfigured to heat at least one of the thermal storage blocks;

a fluid movement system (213, 4223) configured to direct a stream of afirst fluid through the fluid pathways to heat the first fluid to aspecified temperature range;

a first steam generator configured to, using the first fluid, convertinput feed water into steam;

a steam turbine configured to cause generation of electricity using thesteam; and

a preheater configured to, using waste heat from the steam turbine,preheat feed water provided to a second steam generator.

580. The apparatus of claim 579, wherein the first steam generator is aheat recovery steam generator.

581. The apparatus of claim 579, wherein the second steam generator is aonce-through steam generator.

582. The apparatus of claim 579, further comprising a condenser coupledto the steam turbine, wherein the condenser is configured to condensesteam received from the steam turbine into water.

583. The apparatus of claim 582, further comprising a recirculation pumpconfigured to provide, as feed water to the first steam generator, waterproduced by the condenser.

584. The apparatus of claim 579, wherein the second steam generator isconfigured to generate steam using a second fluid from a second storagemedium configured to store thermal energy.

585. The apparatus of claim 579, wherein the preheater is configured tooutput a third fluid to the thermal storage assemblage.

Apparatus using heat from thermal storage assemblage to generate steamwith feedback to maintain steam quality.

586. An apparatus comprising:

a thermal storage assemblage (4100) including a plurality of thermalstorage blocks, wherein at least some of the thermal storage blocksinclude multiple fluid flow slots, wherein at least some of the fluidflow slots are configured to define fluid pathways through the thermalstorage blocks;

a plurality of heater elements (3607) positioned within the thermalstorage assemblage, wherein each of the plurality of heater elements isconfigured to heat at least one of the thermal storage blocks;

a fluid movement system (213, 4223) configured to direct a stream offluid through the fluid pathways to heat the fluid to a specifiedtemperature range;

a steam generator configured to receive the fluid to convert input feedwater into input steam;

a measurement unit configured to determine a measured steam qualityvalue of steam output from the steam generator; and

a controller configured to cause the cause the fluid movement system todirect the stream of fluid, and further configured to use the measuredsteam quality as feedback to adjust a flow rate of the fluid to maintainthe measured steam quality within a specified steam quality range.

587. The apparatus of claim 586, wherein the measurement unit includes aseparator configured to separate steam output from the steam generatorfrom water vapor output from the steam generator, wherein themeasurement unit is configured to determine the measured steam qualitybased on fraction of the water vapor output from the steam generatorrelative to the steam output from the steam generator.

588. The apparatus of claim 586, wherein the measurement unit isconfigured to determine the steam quality based on a flow velocity ofsteam output from the steam generator and a mass flow rate of the inputfeed water.

589. The apparatus of claim 586, wherein the steam generator is aonce-through steam generator.

590. The apparatus of claim 586, wherein the controller is configured tocause delivery of steam in accordance within a specified range of steamdelivery rates.

591. The apparatus of claim 590, wherein the controller is configured tospecify the range of steam delivery rates based on forecast information.

592. The apparatus of claim 591, wherein the forecast informationincludes weather forecast information.

593. The apparatus of claim 591, wherein the forecast informationincludes expected electricity rates.

594. The apparatus of claim 591, wherein the forecast informationincludes expected steam demand.

Cogeneration system using heat from electrolysis process to generatesteam input to a once-through steam generator.

595. A system comprising:

a storage medium configured to store thermal energy generated by aconversion of input electricity from an input energy supply, the inputenergy supply having intermittent availability;

a fluid movement device configured to move fluid through the storagemedium to heat the fluid to a specified temperature, the fluidcomprising oxygen and nitrogen, wherein the fluid movement device isconfigured to provide the fluid at the specified temperature to a solidoxide cell electrolysis system that converts water to hydrogen andenriches the fluid with oxygen; and

a once-through steam generator configured to, using the fluid receivedfrom the electrolysis system convert input feed water into steam.

596. The system of claim 595, further comprising a steam turbineconfigured to cause an electrical generator to generate of electricityusing steam received from the steam generator.

597. The system of claim 595, wherein the thermal storage unit comprisesa plurality of bricks.

598. The system of claim 595, further comprising a controller configuredto cause the fluid movement device to move fluid at a particular rate.

599. The system of claim 598, further comprising a measurement unitconfigured to measure a parameter of steam output from the steamgenerator.

600. The system of claim 598, wherein the controller is configured toadjust the particular rate based on the measurement of the parameter ofsteam output.

601. The system of claim 598, wherein the measurement unit comprises aseparator configured to measure a quality of the steam output from thesteam generator by separating the steam into a liquid phase and a vaporphase.

602. The system of claim 598, wherein the measurement unit is configuredto measure a velocity of steam output from the steam generator.

603. The system of claim 598, wherein the controller is configured tocontrol an amount of fluid moved through the storage medium based on aweather forecast.

604. The system of claim 598, wherein the controller is configured tocontrol and amount of fluid moved through the storage medium based on anexpected difference in electricity costs on a first day and a secondday.

605. The system of claim 595, wherein the intermittent energy supplycomprises a thermophotovoltaic generation system configured to convertthermal radiation into electrical energy.

606. The system of claim 595, wherein the intermittent energy supplycomprises a wind turbine configured to generate electricity.

607. The system of claim 595, wherein the intermittent energy supplycomprises a solar energy source configured to convert solar energy intoelectricity.

608. The system of claim 595, wherein the fluid movement devicecomprises a closed fluid recirculation loop.

609. The system of claim 595, further comprising a pump, and wherein thepump is configured to force the input feed water through one or moreconduits of the steam generator.

610. The system of claim 609, wherein the one or more conduits mountedin the steam generator transversely to a path fluid flow.

System for cogeneration using steam output from a steam turbine in anindustrial process, reducing waste of energy.

611. A system comprising:

a storage medium configured to store thermal energy generated by aconversion of input electricity from an input energy supply, the firstinput energy supply having intermittent availability;

a first fluid movement device configured to move fluid through thestorage medium to heat the fluid to a specified temperature;

a once-through steam generator configured to, using the fluid, convertinput feed water into an input steam having a first pressure;

a steam turbine configured to provide an output steam at a secondpressure that is less than the first pressure; and

a second fluid movement device configured to move the output steam foruse in an industrial process.

612. The system of claim 611, wherein the steam turbine is configured tocause generation of electricity by an electrical generator.

613. The system of claim 612, wherein the electrical generator isconfigured to provide electricity to a power grid.

614. The system of claim 611, wherein the industrial process comprisesproduction of biofuels.

615. The system of claim 611, wherein the industrial process comprisesproduction of petroleum-based fuels.

616. The system of claim 611, wherein the industrial process comprisesproduction of diesel fuels.

617. The system of claim 611, wherein industrial process comprisesdrying of grains.

618. The system of claim 611, further comprising a controller configuredto cause the steam generator to generate steam at a specified steamquality based on steam quality.

619. The system of claim 618, further comprising a measurement unitconfigured to determine the steam quality based on separation of steamand water vapor output from the steam generator.

620. The system of claim 618, further comprising a measurement unitconfigured to determine the steam quality based on measurements of steamoutlet flow and feed water input flow.

621. The system of claim 618, wherein the controller is configured tocontrol a rate at which fluid is moved through the storage device by thefirst fluid movement device.

622. The system of claim 611, wherein the storage medium comprises aplurality of bricks.

System for cogeneration using steam output from a steam turbine is inputto a steam generator, reducing waste of energy.

623. A system comprising:

a first storage medium configured to store thermal energy generated by aconversion of input electricity from an input energy supply, the inputenergy supply having intermittent availability;

a fluid movement device configured to move fluid through the storagemedium to heat the fluid to a specified temperature;

a first steam generator configured to, using the fluid, convert firstinput feed water into steam;

a steam turbine configured to, using the steam, cause an electricalgenerator to generate electricity; and

a preheater configured to, using waste heat from the steam turbine,preheat second feed water provided to a second steam generator.

624. The system of claim 623, wherein the second steam generator is aonce-through steam generator.

625. The system of claim 623, further comprising a condenser configuredto receive at least a portion of the steam from the steam turbine andconfigured to condense the portion of steam into third feed water.

626. The system of claim 625, further comprising a recirculation pumpconfigured to provide the third feed water to the first steam generator.

627. The system of claim 623, wherein the steam generator is a heatrecovery steam generator.

628. The system of claim 623, further comprising:

-   -   a measurement unit configured to determine a measured output        steam quality; and

a controller configured to adjust a current output steam quality towithin a specified range using the measured output steam quality asfeedback.

629. The system of claim 628, wherein the controller is configured tocause fluid movement device to adjust a rate of fluid flow through thestorage medium in accordance with the feedback and the specified rangeof steam quality.

Method for optimizing use of available VRE.

630. A method for controlling the distribution of electrical powerderived from a renewable energy source received at a power managementfacility, including the steps of:

determining a first demand for a first use of the power, and providing afirst portion of the power to the first use;

determining a second demand for a second use of the power and, if afirst excess amount of power is available once the first portion hasbeen provided to the first use sufficient to meet the first demand,providing a second portion of the first excess amount of power to thesecond use; and

if a second excess amount of power is available once the second portionhas been provided to the second use sufficient to meet the seconddemand, providing the second excess amount of power to a third use.

631. The method of claim 630, wherein:

the first use is electrical demand of an industrial facility; and

the second use is an electrolysis process for producing hydrogen.

632. The method of claim 630, wherein the third use includes providingat least a portion of the second excess amount of power to a thermalcharging apparatus of a thermal storage unit.

633. The method of claim 630, wherein the third use includes providingat least a portion of the second excess amount of power to an electricalpower grid.

634. The method of claim 630, wherein the third use includes providingat least a portion of the second excess amount of power to a thermalcharging apparatus of a thermal storage unit.

635. The method of claim 630, wherein the third use includes providingat least a portion of the second excess amount of power to a thermalcharging apparatus of a thermal storage unit, and further including thesteps of:

determining whether the thermal storage unit has been fully charged, andif so, providing a remaining portion of the second excess amount ofpower to an electrical power grid.

Configurations of TES system components.

636. A system for thermal energy storage and delivery, comprising:

a thermal storage assemblage including a plurality of thermal storageblocks, wherein at least some of the thermal storage blocks includemultiple radiation cavities and multiple fluid flow slots, wherein someof the radiation cavities and some of the fluid flow slots areconfigured to define fluid pathways through the thermal storage blocks;

a plurality of heater elements positioned within the thermal storageassemblage and adjacent to at least some of the radiation cavities,wherein each of the plurality of heater elements is configured to heatat least one of the thermal storage blocks via energy radiated intomultiple ones of the radiation cavities and onto surfaces that bound therespective radiation cavities; and

a fluid movement system configured to direct a stream of fluid throughthe fluid pathways;

with any one or more of the following components or characteristics:

(a) the heater element pathway includes one or more slots configured tohang a heater element;

(b) the thermal storage blocks include shelf portions that interlockwhen the thermal storage blocks are positioned in a stack;

(c) the thermal storage blocks include multiple substantiallyrectangular portions that each include multiple openings to other tiersand that bound different cavities of one or more tiers;

(d) one or more stacks of thermal storage blocks in the TSU arepositioned using space elements;

(e) the thermal storage blocks of the first and second tiers are stackedwithout spacing between tiers; and

(f) at least half of a surface of at least a portion of a particularthermal storage block thermal storage material is not an opening, i.e.there relatively small slits through the brick, compared to the size ofthe radiation cavity.

Carbon Capture

637. A system that includes:

-   -   a carbon dioxide capture system configured to separate carbon        dioxide from exhaust gases;    -   a thermal storage system configured to convert input electricity        from an input energy supply to stored thermal energy, the input        energy supply having intermittent availability; and    -   a power generation system configured to:        -   convert a portion of the stored thermal energy to output            electricity via a turbine; and        -   provide the output electricity and turbine waste heat to the            carbon dioxide capture system;    -   wherein the carbon dioxide capture system is configured to        operate using the provided electricity and heat.

638. The system of claim 637, wherein the thermal storage systemincludes:

-   -   a heating element configured to heat a storage medium using the        input electricity from the input energy supply; and    -   a blower configured to circulate fluid through the heated        storage medium.

639. The system of claim 637 or 638, wherein the power generation systemincludes:

-   -   a heat exchanger configured to generate steam using circulated        fluid; and    -   a steam turbine configured to generate the supplied electricity        from the produced steam.

640. The system of any one of claims 637 to 639, wherein the carbondioxide capture system is configured to use a portion of stored thermalenergy as heat to separate the carbon dioxide from the exhaust gases.

641. The system of any one of claims 637 to 640, wherein the thermalenergy storage system is further configured to generate the outputelectricity in a substantially continuous manner.

642. A method that includes:

-   -   converting, by a thermal energy storage system, input        electricity from an intermittently availability energy supply to        stored thermal energy;    -   converting, by the thermal energy storage system and a turbine,        the stored thermal energy to output electricity; and    -   providing, by the thermal energy storage system, the output        electricity to a carbon dioxide capture system that separates        carbon dioxide from exhaust gases, wherein the output        electricity is provided at least at times when the energy supply        is not available.

643. A method that includes:

-   -   receiving, by a carbon dioxide capture system, exhaust gases        from combustion of a fuel source;    -   receiving, by the carbon dioxide capture system, electricity and        heat generated from a thermal energy storage system and turbine,        wherein the thermal energy storage system stores thermal energy        using an intermittently availability energy supply; and    -   separating, by the carbon dioxide capture system, carbon dioxide        from exhaust gases using the received electricity and heat,        wherein the separating is performed at least at times in which        the energy supply is not available.

What is claimed is:
 1. A thermal energy storage system, comprising: astorage medium configured to store thermal energy; a heating elementconfigured to heat the storage medium using electricity from a renewableenergy source; and a fluid movement system configured to move a fluidthrough the storage medium to heat the fluid to a temperature in aspecified electrolyzer temperature range and to provide the fluid to asolid oxide unit configured to operate in an electrolysis mode toproduce hydrogen and/or carbon monoxide, wherein the fluid is passedthrough the solid oxide unit to heat the solid oxide unit.
 2. The systemof claim 1, wherein: the specified electrolyzer temperature range is700° C. to 900° C.; and the thermal energy storage system is configuredto extract heat from the fluid after it has been provided to the solidoxide unit, and to provide the extracted heat to a secondary process. 3.The system of claim 1, wherein the fluid movement system is configuredto recirculate at least a portion of an output byproduct fluid to thethermal storage medium to be reheated.
 4. The system of claim 1,wherein: the solid oxide unit includes a solid oxide electrolysis cellhaving an electrolysis anode and an electrolysis cathode; the fluidmovement system is configured to split the fluid into an electrolysisanode-side flow conduit and an electrolysis cathode-side flow conduit;the electrolysis anode-side flow conduit is configured to permit oxygento be swept from the electrolysis anode; and the electrolysiscathode-side flow conduit is configured to permit the electrolysiscathode-side flow to exit the solid oxide unit with output products fromthe electrolysis cathode mixed therein.
 5. The system of claim 4,wherein the fluid comprises water or carbon dioxide, or a combinationthereof.
 6. The system of claim 4, wherein: the fluid comprises water assteam; the fluid movement system is configured to provide a sweep gas toremove the oxygen from the electrolysis anode to a secondary oxygenprocess; the output products from the electrolysis cathode includehydrogen; and the fluid movement system is configured to provide thehydrogen to a secondary hydrogen process.
 7. The system of claim 4,wherein: the electrolysis cathode-side flow comprises steam and carbondioxide; the output products from the electrolysis cathode includesyngas; and the fluid movement system is configured to flow to asecondary syngas process.
 8. The system of claim 1, wherein: the fluidcomprises a first fluid and a second fluid; the fluid movement system isconfigured to transport the first fluid to an electrolysis cathode ofthe solid oxide unit through a first fluid delivery system where thefirst fluid delivery system is configured to supply heat and cathodereactants to the electrolysis cathode; and the fluid movement system isconfigured to transport the second fluid to an electrolysis anode of thesolid oxide unit through a second fluid delivery system where the secondfluid delivery system is configured to supply heat to the electrolysisanode and sweep away anode byproducts.
 9. The system of claim 8,wherein: the first fluid delivery system is configured to transportoutput products in an electrolysis cathode-side fluid to a secondarycathode-side process; and the second fluid delivery system is configuredto provide anode byproducts from an electrolysis anode-side fluid to asecondary anode-side process.
 10. The system of claim 8, wherein: thefirst fluid comprises steam and carbon dioxide; the output productsinclude syngas; and the fluid movement system is configured to use thesyngas in a secondary syngas process.
 11. The system of claim 1,wherein: the specified electrolyzer temperature range is hotter than anintended operating temperature of the solid oxide unit; and the systemis configured to increase the production of carbon monoxide and/orhydrogen per unit electricity used by the solid oxide unit by providingheat from the heated fluid as a portion of an input electrolysisreaction energy for the solid oxide unit to reduce an amount ofelectricity required for the electrolysis.
 12. The system of claim 1,wherein: the solid oxide unit is configured to operate in either theelectrolysis mode or a fuel cell mode; and the fluid movement system isconfigured to move the fluid through the storage medium to heat thefluid to a temperature in a specified fuel cell temperature range,provide the fluid to the solid oxide unit in the fuel cell mode, removeexcess heat from the solid oxide unit in the fluid, and provide thefluid to a secondary process.
 13. A method, comprising: convertingelectricity from a renewable energy source into heat; supplying the heatto a thermal storage medium; circulating a fluid through the thermalstorage medium to heat the fluid to a temperature in a specifiedelectrolyzer temperature range; providing the fluid to a solid oxideunit configured to operate in an electrolysis mode to produce hydrogenfrom water and/or carbon monoxide from carbon dioxide; and heating thesolid oxide unit by passing the fluid through the solid oxide unit. 14.The method of claim 13, wherein: the specified electrolyzer temperaturerange is 700° C. to 900° C., and further comprising: extracting heatfrom the fluid after it has been provided to the solid oxide unit; andproviding the extracted heat to a secondary process.
 15. The method ofclaim 13, wherein the fluid is oxygen and nitrogen, water, air, carbondioxide, or a combination thereof.
 16. The method of claim 13 furthercomprising: splitting the fluid into an electrolysis cathode-side flowand an electrolysis anode-side flow, wherein the solid oxide unitcomprises an electrolysis cathode and an electrolysis anode; deliveringwater and/or carbon dioxide to the electrolysis cathode; sweeping theelectrolysis anode-side flow from the electrolysis anode, wherein theswept electrolysis anode-side flow includes oxygen; and discharging theelectrolysis cathode-side flow with output products mixed therein fromthe electrolysis cathode.
 17. A thermal energy storage system,comprising: a thermal storage medium configured to store thermal energy;a heating element configured to heat the thermal storage medium usingelectricity from a renewable energy source; and a fluid movement systemconfigured to: move a fluid through the thermal storage medium to heatthe fluid to a temperature in a specified fuel cell temperature range;provide the fluid to a solid oxide unit that is configured to operate ina fuel cell mode to generate electricity; remove excess heat from thesolid oxide unit in the fluid; and provide the fluid to one or moresecondary processes.
 18. The system of claim 17, wherein: the one ormore secondary processes includes a thermal cycle power generationsystem configured to generate electricity.
 19. The system of claim 17,wherein the specified fuel cell temperature range is between 700° C. and900° C.
 20. The system of claim 17, wherein: the fluid movement systemis configured to wash over one or more electrodes of the solid oxideunit to produce one or more output streams; and the fluid movementsystem is configured to extract a first portion of the heat energy of atleast one of the one or more output streams and to provide the firstportion of the heat energy to the one or more secondary processes. 21.The system of claim 20, wherein the one or more secondary processesincludes a refinery process.
 22. The system of claim 20, wherein thefluid movement system is configured to extract a further portion of theheat energy of the one or more output streams and to provide the furtherportion of the heat energy to a tertiary system.
 23. The system of claim22, wherein the tertiary system is configured to preheat a reactantstream and provide the preheated reactant stream to the solid oxideunit.
 24. The system of claim 20, wherein the fluid movement system isconfigured to recirculate at least a portion of the one or more outputstreams to the storage medium to be reheated.
 25. The system of claim17, wherein: the solid oxide unit includes a solid oxide fuel cellhaving a fuel cell cathode and a fuel cell anode; the fluid movementsystem is configured to permit the fluid to be delivered to a fuel cellcathode-side flow conduit and preheat a fuel cell anode-side reactantstream that flows to a fuel cell anode-side flow conduit; the fuel cellcathode-side flow conduit is configured to permit oxygen to be deliveredto the fuel cell cathode to remove heat from the solid oxide unit andprovide the heat to the one or more secondary processes; and the fuelcell anode-side flow conduit is configured to permit the fuel cellanode-side flow to exit the solid oxide unit and provide fuel cellanode-side reaction products to the one or more secondary processes. 26.The system of claim 25, wherein: the fluid comprises oxygen or air; thefuel cell anode-side reactant stream comprises hydrogen and/or carbonmonoxide; and the fluid movement system is configured to provide thefuel cell cathode-side flow to the one or more secondary processes. 27.The system of claim 25, wherein: the fluid comprises oxygen; the fuelcell anode-side reactant stream includes hydrogen or carbon monoxide ora combination thereof; and the solid oxide unit is configured to produceelectricity and provide the electricity to the one or more secondaryprocesses.
 28. The system of claim 17, wherein: the solid oxide unit isconfigured to operate in either the fuel cell mode or an electrolysismode; and the fluid movement system is configured to move the fluidthrough the storage medium to heat the fluid to a temperature in aspecified electrolyzer temperature range, provide the fluid to the solidoxide unit in the electrolysis mode, remove the fluid from the solidoxide unit, and provide the fluid to a secondary process.
 29. A method,comprising: converting electricity from a renewable energy source intoheat; supplying the heat to heat a thermal storage medium; circulating afluid through the thermal storage medium to heat the fluid to atemperature in a specified fuel cell temperature range; providing theheated fluid to maintain a desired operating temperature of a solidoxide unit configured to operate in a fuel cell mode; generatingelectricity within the heated solid oxide unit from hydrogen and/orcarbon monoxide; absorbing excess heat from the solid oxide unit intothe fluid; removing the fluid from the solid oxide unit; and providingthe fluid from the solid oxide unit to one or more secondary processes.30. The method of claim 29 further comprising: delivering the fluid to afuel cell cathode-side flow conduit, wherein the fuel cell cathode-sideflow conduit delivers oxygen to a fuel cell cathode; and preheating afuel cell anode-side reactant stream that flows to a fuel cellanode-side flow conduit with the fluid before or after the fluid passesthrough the solid oxide unit.